UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

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

For the quarterly period ended ~~January~~April 3130, 2010

TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from _______ to _______

Commission File Number: ~~333~~000-~~141480~~53728

KENTUCKY USA ENERGY, INC.

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

Delaware	20-5750488
(State of incorporation)	(IRS Employer Identification No.)
(State or other jurisdiction of incorporation	(IRS Employer Identification No.)
or organization)

321 Somerset Road, Suite 1

London, KY 40741

(Address of principal executive offices)

(606) 878-5987

(~~Issuer~~Registrant’s telephone number)

N/A

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

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes ¨ No ¨

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

Large accelerated filer ¨		Accelerated filer ¨		Non-accelerated filer ¨		Smaller reporting company þ
				(Do not check if a smaller Reporting company)

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

There were 36,927,092 shares of the issuer’s common stock outstanding as of ~~March~~June 1721, 2010.

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

KENTUCKY USA ENERGY, INC.

Condensed Consolidated Balance Sheets

	January 31, 2010			October 31, 2009
	April 30, 2010
	Unaudited			October 31, 2009
ASSETS
Current Assets
Cash and cash equivalents	$	~~477~~109,~~487~~212		$	59,105
Prepaid expenses		23,492			37,006
Accounts receivable		12,232			-
Total current assets		500,979			96,111
Prepaid expenses		10,282			37,006
Total Current Assets		131,726			96,111
Other Assets
Loan fees, net of accumulated amortization of $235,987 and $509,511		549,595			640,694
Loan fees, net of accumulated amortization of $691,709 and $509,511		458,496			640,694
Investment in natural gas properties using full cost method, net of depletion of $2,800 and $0		8,124,542			7,708,811
Investment in natural gas properties, using full cost method, net of depletion of $5,600 and $0		8,712,295			7,708,811
Total other assets		8,674,137			8,349,505
Total Other Assets		9,170,791			8,349,505
Other property and equipment, net of accumulated depreciation of $53,181 and $42,258		462,727			450,650
Other property and equipment, net of accumulated depreciation of $64,142 and $42,258		453,990			450,650
Total assets	$	9,637,843		$	8,896,266
Total Assets	$	9,756,507		$	8,896,266
LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
Current Liabilities
Accounts payable	$	~~112~~164,~~038~~912		$	343,890
Accrued interest		~~491~~707,~~799~~310			522,303
Accrued liabilities		79,~~996~~308			7,763
Stock liability		~~156~~164,~~775~~275			149,125
Derivative liability		770,686			1,015,971
Derivative liability - warrants		95,499			1,015,971
Notes payable, due within one year		7,500,000			6,300,000
Notes payable		7,500,000			6,300,000
Capital lease obligations, due within one year		94,847			94,847
Capital lease obligations		94,847			94,847
Total current liabilities		9,134,141			8,433,899
Total Current Liabilities		8,736,151			8,433,899
Long-term Debt
Convertible debt, net of discounts of $1,319,446 and $1,527,779		1,180,554			972,220
Convertible debt, net of discounts of $1,111,113 and $1,527,780		1,388,887			972,220
Capital lease obligations, less amounts due within one year		80,807			110,083
Capital lease obligations		66,169			110,083
Total long-term debt		1,261,361			1,082,303
Total Long-term Debt		1,455,056			1,082,303
Total liabilities		10,395,502			9,516,202
Total Liabilities		10,191,207			9,516,202
Stockholders' Equity (Deficit)
Preferred stock (20,000,000 shares authorized, none issued)
Common stock, ($0.0001 par value; 300,000,000 shares authorized; 36,927,092 and 36,927,092 shares issued and outstanding)		3,692			3,692
Additional paid-in capital		4,298,928			4,298,928
Accumulated (Deficit)		(54,~~060~~737,~~279~~320	)		(4,922,556	)
Total stockholders' (deficit)		(757,659	)		(619,936	)
Total Stockholders' (Deficit)		(434,700	)		(619,936	)
Total liabilities and stockholders' deficit	$	9,637,843		$	8,896,266
Total Liabilities and Stockholders' Equity (Deficit)	$	9,756,507		$	8,896,266

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

KENTUCKY USA ENERGY, INC.

~~Consolidated~~Condensed Consolidated Statements of Operations

	For the Three Months			For the Three Months
	Three Months			Three Months			Six Months			Six Months
	Ended			Ended			Ended			Ended
	January 31, 2010			January 31, 2009
	April 30, 2010			April 30, 2009			April 30, 2010			April 30, 2009
Revenues
	Unaudited			Unaudited			Unaudited			Unaudited
Gas revenues	$	32,360		$	-
Revenues	$	61,278		$	-		$	93,638		$	-
Costs and expenses
General and Administrative Expenses
Production costs and taxes		2944,~~836~~829			-			74,665
Depletion expense		2,800			-
Depreciation and depletion		13,761						27,484
Amortization of loan fees		91,099			91,099			182,198			182,198
General and administrative		3726,~~001~~413			4223,~~622~~704			52,491			66,327
Compensation expense (including $21,741 and $230,500 of share-based compensation)		107,059			347,698
Compensation expense (including $19,250, $226,500, $40,991 and $457,000 of share-based compensation)		105,200			322,500			212,259			670,198
Legal and accounting		7658,~~023~~009			3663,~~907~~855			134,032			100,762
Total costs and expenses		~~343~~339,~~818~~311			~~518~~501,~~326~~158			683,129			1,019,485
(Loss) from operations		(~~311~~278,~~458~~033	)		(~~518~~501,~~326~~158	)		(589,491	)		(1,019,485	)
Other income (expense)
Other Income (expense)
Changes in fair value of derivative liability		~~245~~675,~~285~~187			~~(66~~327,~~285~~427	)		920,472			261,143
Interest (expense)		(71,550	)		(74,137	)
Interest expense		(74,194	)		(205,169	)		(145,745	)		(279,305	)
(Loss) before income taxes		(137,723	)		(658,747	)
Net income (loss) before income taxes		322,960			(378,900	)		185,236			(1,037,647	)
Income taxes		-			-			-			-
Net (Loss)	$	(137,723	)	$	(658,747	)
Net income (loss)	$	322,960		$	(378,900	)	$	185,236		$	(1,037,647	)
Net loss per share
Net income (loss) per share
Basic and diluted:
Basic and diluted	$	0.01		$	(0.01	)	$	-		$	(0.03	)
Operations	$	(0.00	)	$	(0.02	)
Total	$	(0.00	)	$	(0.02	)

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

KENTUCKY USA ENERGY, INC.

~~Statement~~Condensed Consolidated Statement of Changes in Stockholders’ Deficit

For the period ended ~~January~~April 3130, 2010

							Deficit
										Total
	Common				Additional		~~Accumulated~~			~~Total~~Stockholders’
	Stock		Common		Paid -in		~~During Exploration~~Accumulated			~~Stockholders’~~Equity
	Shares		Stock		Capital		~~Stage~~Deficit			(Deficit)
Balance at October 31, 2009		36,927,092	$	3,692	$	4,298,928	$	(4,922,556	)	$	(619,936	)
Net loss for the period		-		-		-		(137,723	)		(137,723	)
Net income for the period		-		-		-		185,236			185,236
Balance at January 31, 2010		36,927,092	$	3,692	$	4,298,928	$	(5,060,279	)	$	(757,659	)
Balance at April 30, 2010		36,927,092	$	3,692	$	4,298,928	$	(4,737,320	)	$	(434,700	)

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

KENTUCKY USA ENERGY, INC.

Condensed Consolidated Statements of Cash Flows

	For the Three Months			For the Three Months
	Six Months			Six Months
	Ended			Ended
	January 31, 2010			January 31, 2009
	April 30, 2010			April 30, 2009
Net loss	$	(137,723	)	$	(658,747	)
	Unaudited			Unaudited
Adjustments to reconcile net loss to net cash flows from operating activities
Net income (loss)	$	185,236		$	(1,037,647	)
Gain on market valuation of derivative liabilities		(245,285	)		66,284
Adjustments to reconcile net income (loss) to net cash flows from operating activities
Amortization of loan fees		299,433			-
Gains on market valuation of derivative liabilities		(920,472	)		(261,143	)
Depreciation		10,923			8,129
Discount on convertible debt		416,667			416,667
Depletion		2,800			-
Amortization of loan fees		182,198			182,198
(Increase)decrease in assets and increase (decrease) in liabilities
Depreciation		21,884			16,432
Prepaid expenses		13,514			10,170
Accounts receivable		(12,232	)
Accounts payable and accrued liabilities		(231,619	)		96,812
Depletion		5,600			-
Stock liability		7,650			230,500
(Increase) decrease in assets and increase (decrease) in liabilities
Accrued interest		(30,504	)		-
Prepaid expenses		26,725			10,115
Total adjustments to reconcile net loss to net cash from operating activities		(173,088	)		411,895
Accounts payable and accrued liabilities		(177,433	)		121,065
Net cash flows from operating activities		(310,811	)		(246,852	)
Stock liability		15,150			457,000
Accrued interest		185,007			-
Total adjustments to reconcile net income (loss) to net cash flows from operating activities		(256,906	)		942,334
Net cash flows from operating activities		(71,670	)		(95,313	)
Cash flows from investing activities
Purchase of other property and equipment		(2325,~~000~~225	)		(1680,~~064~~621	)
Investment in oil & gas properties		(~~418~~1,~~531~~009,084	)		(~~537~~2,~~716~~400,709	)
Total cash flows from investing activities		(441,531	)		(553,780	)
Net cash flows from investing activities		(1,034,309	)		(2,481,330	)
Cash flows from financing activities
Proceeds from borrowings		1,200,000			-2,500,000
Payments on capital lease obligations		(29,276	)		(14,637	)
Payments of capital lease obligation		(43,914	)		(43,913	)
Total cash flows from financing activities		1,~~170~~156,~~724~~086			~~(14~~2,~~637~~456,087	)
Net change in cash		418,382			(815,269	)
Net (decrease) increase in cash		50,107			(120,556	)
Cash and cash equivalents, beginning of period		59,105			899,037
Cash and cash equivalents, end of period	$	~~477~~109,~~487~~212		$	83778,~~768~~481
Supplemental Disclosures of Cash Flow information
Cash paid for interest	$	66137,~~783~~566		$	50215,833

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

Kentucky USA Energy, Inc.

Notes to Condensed Financial Statements

(Unaudited)

(1) Basis of Presentation

The accompanying unaudited condensed consolidated financial statements of Kentucky USA Energy, Inc. (“the “Company”) have been prepared in accordance with accounting principles generally accepted ~~accounting~~in ~~principles~~the United States of America (“US GAAP”) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by US GAAP for complete financial statements. In the opinion of management, all adjustments consisting of normal recurring adjustments considered necessary for fair presentation have ~~been~~ been included. Operating results for the three and six months ended April ~~January 31~~30, 2010 are not necessarily indicative of the results that may be expected for the year ended October 31, 2010.

The ~~financial statements do not~~ ~~include any adjustments that could be required if the~~ Company ~~were unable to refinance debt or continue as a going concern. The Company~~ has incurred substantial losses, which have strained its financial resources,. ~~and, at~~At ~~January~~April 3130, 2010, the Company’s liabilities exceed its assets. The Company is currently in default on the senior credit facility with NSES, LLC (“NSES”) and the NSES loan may be called. Additionally, the Company is behind schedule on drilling as specified in the K & D farm-out, and currently does not have the funds to complete these drillings over the expected life of the K & D Assignments. ~~and~~Additional funds will ~~require~~be required ~~additional funds~~ to do so. In the event the Company cannot raise the necessary funds or does not drill the required 12 wells per year, the Company might lose the rights to the K & D Properties. Thus, if the Company is unable to raise sufficient additional capital through debt and equity offerings or K & D successfully forecloses under the terms of the farm-out, liquidity problems will cause the Company to curtail operations, liquidate or sell assets or entities, or pursue other actions that could adversely affect future operations. These factors have raised doubt about the Company’s ability to continue as a going concern. ~~For~~ For these reasons our auditors state in their report on our audited financial statements for the year ended October 31, 2009 that they have a substantial doubt we will be able to continue as a going concern.

To mitigate the effects of the above problems, management plans to work with NSES on its technical default and is looking at options for raising additional capital. ~~Management~~The ~~continues to work with K&D’s principals, and the principals have continued to assist the~~ Company ~~in implementing its plans. Additionally, the Company~~ entered into additional agreements with a K&D ~~principal~~ principal in ~~January~~April, 2010., and Management ~~has~~continues ~~maintained~~to ~~good~~work ~~relations~~ with ~~the principals and does not believe the Company~~K&D’s ~~failure~~principals, ~~to adhere to~~ and the ~~specified schedule~~principals ~~will~~have ~~lead~~continued to aassist ~~material~~the ~~loss~~Company toin ~~the~~implementing ~~Company~~its plans.

Certain amounts in prior periods have been reclassified to conform to the report classifications of the quarter ended ~~January~~April 3130, 2010 with no effect on ~~previously~~ previously reported net income or stockholders’ equity.

(2) Earnings per Share

In accordance with of Financial Accounting Standards (“FASB”) Accounting Standards Codification (“ASC”) 260-10, Earnings Per Share, basic income per share is based on 36,927,092 weighted average shares outstanding for the quarter ended April 30, 2010. Diluted earnings per common share are computed by dividing income available to common shareholders by the weighted average number of shares of common stock outstanding during the period increased to include the number of additional shares of common stock that would have been outstanding if the dilutive potential shares of common stock had been issued. Because the Company had incurred losses from inception, for 2009 periods presented all potentially dilutive securities were anti-dilutive. For the three and six months ended April 30, 2010, the potential effects of the issuance of warrants and conversion of debt were anti-dilutive.

(3) Recent Accounting Pronouncements

In January 2010, the FASB issued ASU 2010-06, “Fair Value Measurements and Disclosures (Topic 820): Improving Disclosures about Fair Value Measurements”. This update requires more robust disclosures about valuation techniques and inputs to fair value measurements. The update is effective for interim and annual reporting periods beginning after December 15, 2009. The Company has adopted the update. There was no material effect on the Company’s consolidated financial statements.

Kentucky USA Energy, Inc.

Notes to Condensed Financial Statements

(Unaudited)

(23) ~~Earnings per~~Recent ~~Share~~Accounting Pronouncements (continued)

InEffective ~~accordance~~July ~~with~~1, 2009, the ~~Financial~~Company adopted the FASB ASC 105-10, Generally Accepted Accounting ~~Standards~~Principles ~~Board~~– (“Overall which establishes the FASB”) Accounting ~~Standards~~ Standards Codification (the “~~ASC~~Codification”) ~~260-10,~~as ~~Earnings~~the ~~Per~~source ~~Share,~~of ~~basic~~authoritative ~~income~~accounting ~~per~~principles ~~share~~recognized isby ~~based~~the onFASB ~~36,927,092~~to ~~weighted~~be ~~average~~applied ~~shares~~by ~~outstanding for~~nongovernmental entities in the ~~quarter~~preparation ~~ended~~of ~~January 31,~~financial statements in conformity with U.S. ~~2010~~GAAP. ~~Diluted~~Rules ~~earnings~~and ~~per~~interpretive ~~common~~releases ~~share~~of ~~are~~the ~~computed~~SEC byunder ~~dividing~~authority ~~income~~of federal ~~available~~securities tolaws ~~common~~are ~~shareholders~~also bysources of authoritative U.S. GAAP for SEC registrants. All guidance contained in the ~~weighted~~Codification ~~average~~carries ~~number~~an ofequal ~~shares~~level of authority. ~~common~~The ~~stock~~Codification ~~outstanding~~superseded ~~during~~all ~~the~~existing ~~period~~non-SEC ~~increased~~accounting toand ~~include~~reporting standards and all other non-grandfathered, non-SEC accounting literature not included in the ~~number~~Positions ofor Emerging Issues Task Force (“EITF”) Abstracts. ~~additional~~Instead, ~~shares~~it ofwill ~~common~~issue ~~stock~~ASUs. ~~that~~The ~~would~~FASB ~~have~~will ~~been~~not ~~outstanding~~consider ifASUs as authoritative in their own right. ASUs will serve only to update the Codification, provide ~~dilutive~~background ~~potential~~information ~~shares~~about ofthe ~~common~~guidance ~~stock~~and ~~had~~provide ~~been~~the ~~issued. Because~~bases of conclusions on the change(s) in the Codification. The Company ~~has~~adopted ~~incurred~~the ~~losses~~policy ~~from~~effective September ~~inception~~30, ~~all~~2009. ~~potentially~~There ~~dilutive~~was no material effect on the presentation of the ~~securities~~Company’s ~~are~~consolidated ~~anti-dilutive~~financial ~~for~~statements ~~all~~as ~~periods~~a ~~presented~~result of the adoption of ASC 105.

In May 2009, the FASB issued Statement No. 165, Subsequent Events, which was primarily codified into ASC Topic 855 (3“Topic 855”) ~~Recent~~. Topic 855 establishes ~~Accounting~~general ~~Pronouncements~~standards of accounting for and disclosures of events that occur after the balance sheet date but before financial statements are issued or are available to be issued. In particular, this Statement requires the following: (a) the period after the balance sheet date during which management of a reporting entity should evaluate events or transactions that may occur for potential recognition or disclosure in the financial statements, (b) the circumstances under which an entity should recognize events or transactions occurring after the balance sheet date in its financial statements, and (c) the disclosures an entity should make about events or transactions that occurred after the balance sheet date. In accordance with this Statement, an entity should apply the requirements to interim or annual financial periods ending after June 15, 2009. Topic 855 was updated by FASB ASU 2010-09. This Topic was amended by ASU 2010-09. See above for further discussion of the Company’s treatment.

In ~~May~~ ~~2009~~February, 2010, the FASB issued ~~Statement~~Accounting ~~No.~~Standards ~~165,~~Update ~~Subsequent~~(“ASU”) ~~Events~~2010-09, ~~which was~~ ~~primarily~~effective ~~codified~~immediately, ~~into~~which amended ASC Topic 855, ~~(“Topic~~Subsequent ~~855”).~~Events, ~~Topic 855 establishes~~discussed ~~general~~above. ~~standards~~The ofamendment ~~accounting~~was ~~for~~made ~~and~~to ~~disclosures~~address ofconcerns ~~events~~about ~~that~~conflicts ~~occur~~with ~~after~~SEC ~~the~~guidance ~~balance~~and ~~sheet~~other ~~date~~practice ~~but~~issues. ~~before~~Among ~~financial~~the ~~statements~~provisions ~~are~~of ~~issued~~the oramendment, ~~are~~the ~~available~~FASB todefined bea ~~issued.~~new Intype ~~particular~~of entity, ~~this~~termed ~~Statement~~an ~~requires~~“SEC ~~the~~filer,” ~~following:~~which is an entity ~~(a)~~required ~~the~~to ~~period~~file ~~after~~with ~~the~~or ~~balance~~furnish ~~sheet~~its ~~date~~financial ~~during~~statements ~~which~~to ~~management~~the ofSEC. aEntities ~~reporting~~other ~~entity~~than ~~should~~registrants ~~evaluate~~whose ~~events~~financial orstatements ~~transactions~~are ~~that~~included ~~may~~in ~~occur~~SEC ~~for~~filings ~~potential~~(e.g., ~~recognition~~businesses or ~~disclosure~~real inestate ~~the~~operations ~~financial~~acquired ~~statements,~~or ~~(b)~~to ~~the circumstances~~be ~~under~~acquired, ~~which~~equity method aninvestees, ~~entity~~and ~~should~~entities ~~recognize~~whose ~~events~~securities orcollateralize ~~transactions~~registered ~~occurring~~securities) ~~after~~are ~~the~~not ~~balance~~SEC ~~sheet~~filers. ~~date~~While inan ~~its~~SEC ~~financial~~filer ~~statements,~~is ~~and~~still ~~(c)~~required ~~the~~by U.S. ~~disclosures~~GAAP anto ~~entity~~evaluate ~~should~~subsequent ~~make~~events ~~about~~through ~~events~~the ordate ~~transactions~~its ~~that~~financial ~~occurred~~statements are ~~after~~issued, ~~the~~it ~~balance~~is ~~sheet~~no ~~date.~~longer Inrequired ~~accordance~~to ~~with~~disclose ~~this~~in ~~Statement,~~the anfinancial ~~entity~~statements that it ~~should~~has ~~apply~~done so or the ~~requirements~~date tothrough ~~interim~~which orsubsequent ~~annual~~events ~~financial~~have ~~periods~~been ~~ending~~evaluated. The ~~after~~Company ~~June~~adopted ~~15,~~the ~~2009.~~change ~~Topic~~and ~~855~~does ~~was~~not ~~updated~~believe bythe ~~FASB~~changes ~~Accounting~~have ~~Standards~~a ~~Update~~material ~~(“ASU”)~~impact ~~2010-09.~~on ~~Further~~our ~~discussion~~results of ~~related~~operations ~~accounting~~or ~~treatment~~financial ~~is noted below~~position.

Effective July 1, 2009, the Company adopted the FASB ASC 105-10, Generally Accepted Accounting Principles – Overall which establishes the FASB Accounting Standards Codification (the “Codification”) as the source of authoritative accounting principles recognized by the FASB to be applied by nongovernmental entities in the preparation of financial statements in conformity with U.S. GAAP. Rules and interpretive releases of the SEC under authority of federal securities laws are also sources of authoritative U.S. GAAP for SEC registrants. All guidance contained in the Codification carries an equal level of authority. The Codification superseded all existing non-SEC accounting and reporting standards and all other non-grandfathered, non-SEC accounting literature not included in the Positions or Emerging Issues Task Force (“EITF”) Abstracts. Instead, it will issue ASUs. The FASB will not consider ASUs as authoritative in their own right. ASUs will serve only to update the Codification, provide background information about the guidance and provide the bases of conclusions on the change(s) in the Codification. References made to FASB guidance throughout this document have been updated for the Codification.

Kentucky USA Energy, Inc.

Notes to Condensed Financial Statements

(Unaudited)

(3) Recent ~~accounting~~Accounting ~~pronouncements~~Pronouncements (continued)

On December 31, 2008, the SEC published the final rules and interpretations updating its oil and gas reporting requirements. In January 2010, the ~~FASB~~ FASB released ASU 2010-03, Extractive Activities –— Oil ~~and~~ and Gas (“Topic 932”): Oil and Gas Reserve Estimation and Disclosures aligning U.S. GAAP standards with the SEC’s new rules. Many of the revisions are updates to definitions in the existing oil and gas rules to make them consistent with the ~~petroleum~~ petroleum resource management system, which is a widely accepted standard for ~~the~~ the management of petroleum resources that was developed by several industry organizations. Key revisions include: (a) changes to the pricing used to estimate reserves utilizing a 12-month average price rather than a single day spot price which eliminates the ability to utilize subsequent prices to the end of a reporting period when the full cost ceiling was exceeded and subsequent pricing exceeds pricing at the end of a reporting period, (b) the ability to include nontraditional resources in reserves, (c) the use of new technology for determining reserves, and (d) permitting disclosure of probable and possible reserves. The SEC will require companies to comply with the amended disclosure requirements for registration statements filed after January 1, 2010, and for annual reports on Form 10-K for fiscal years ending on or after December 15, 2009. The ASC is effective for annual periods ending on or after December 31, 2009. The Company does not believe the changes to Topic 932 resulted ~~will~~in ~~have~~ a material impact on our results of operations or financial position. In April 2010, the FASB issued ASU 2010-14, Accounting for Extractive Activities-Oil & Gas: Amendments to Paragraph 932-10-S99-1. This ASU amends terminology as defined in Topic 932-10-S99-1.

On February 24, 2010, the FASB issued ASU 2010-09, effective immediately, which amended ASC Topic 855, Subsequent Events. The amendments were made to address concerns about conflicts with SEC guidance and other practice issues. Among the provisions of the amendment, the FASB defined a new type of entity, termed an “SEC filer,” which is an entity required to file or furnish its financial statements with the SEC. Entities other than registrants whose financial statements are included in SEC filings (e.g., businesses or real estate operations acquired or to be acquired, equity method investees, and entities whose securities collateralize registered securities) are not SEC filers. While an SEC filer is still required by GAAP to evaluate subsequent events through the date its financial statements are issued, it is no longer required to disclose in the financial statements that it has done so or the date through which subsequent events have been evaluated. The Company does not believe the changes have a material impact on our results or financial position.

Kentucky USA Energy, Inc.

Notes to Condensed Financial Statements

(Unaudited)

(4) Natural Gas Properties

The following table sets forth information concerning costs related to the Company’s natural gas property acquisitions, exploration and development activities:

	January 31, 2010		October 31, 2009
	April 30, 2010		October 31, 2009
Property acquisitions:
Development costs	$	6,404,814	$	5,989,038
Development cost	$	6,992,567	$	5,989,083
Leasehold acquisitions		1,719,728		1,719,728
Investment in natural gas properties	$	8,124,542	$	7,708,811
Total	$	8,712,295	$	7,708,811

Interest of $~~405~~420,~~542~~434 and $71446,~~550~~906 was capitalized to natural gas properties during the quarters ending ~~January~~April 3130, 2010 and ~~January~~April 3130, 2009 , respectively.

(5) Credit Facilities

On May 29, 2008 the Company closed a $2,500,000 securities purchase agreement with a private investor. Under the agreement, the Company authorized a ~~senior~~ senior convertible note which is convertible into the Company’s common Stock, par value $0.0001 per share. The note bears interest based on a 360-day year with the first interest payment due August 29, 2008. As amended, the note is ~~interest~~ interest only until the first principal payment, which is due May 29, ~~2010~~ 2011. The note is secured by a lien on substantially all of the Company’s natural gas properties. The note has no financial covenants and the Company is in compliance with all non-financial covenants. The Company incurred closing costs of approximately $651,000 which are being amortized over the term of the note.

On June 25, 2008, the Company closed a $10,000,000 senior credit facility with NSES 12, LLC. Under the facility, the Company may borrow up to $10,000,000. The Company has borrowed $6,850,000 as of ~~January~~April 3130, 2010. The loan under the facility with NSES 12, LLC, bears interest at 12% per year. Interest only is payable during the term of the loan and the principal balance of the loan is due thirty-six months from closing. The facility is secured by a lien on substantially all of the Company’s natural gas properties. The facility has affirmative and negative covenants. The Company is not in compliance of ~~the~~ loan convenants at ~~January~~April 3130, 2010, and accordingly the loan is classified as currently due. The loan proceeds were used for the development of certain oil and gas properties. The Company incurred closing costs associated with the loan of approximately $499,000, which are being amortized over the term of the loan.

9(6) Derivative Liabilities, Beneficial Conversion Feature, Convertible Debt, and Warrants

In June 2008, the Company entered into financing involving derivative investments. The derivative features provided credit enhancement and enabled the Company to access funds on terms that would otherwise not have been available. None of the derivative instruments held by the Company at October 31, 2009 or April 30, 2010 are designed as hedges.

The Company’s derivative instruments include equity contracts consisting of warrant liabilities that the Company will satisfy by issuing a variable number of shares, and conversion features attaching to the Company’s debt.

Kentucky USA Energy, Inc.

Notes to Condensed Financial Statements

(Unaudited)

(6) Derivative Liabilities, Beneficial Conversion Feature, Convertible Debt, and Warrants (continued)

~~In June~~Balances ~~2008,~~related to the ~~Company~~contracts ~~entered into financings involving derivative investments. The derivative features provided credit enhancement~~ and ~~enabled~~included ~~the Company to access funds~~ on ~~terms~~the ~~that~~balance ~~would~~sheets ~~otherwise~~at ~~not~~April ~~have~~30, ~~been available. None of the~~2010 ~~derivative instruments held~~and ~~by the Company at~~ October 31, 2009 ~~or January 31, 2010~~ are ~~designated~~ as ~~hedges.~~ follows:

The Company's derivative instruments include equity contracts consisting of warrant liabilities that the Company will satisfy by issuing a variable number of shares, and conversion features attaching to the Company's debt.

	April 30, 2010		October 31, 2009

Conversion features	$	60,711	$	585,182
Warrant liabilities		34,788		430,789
Derivative Liability	$	95,499	$	1,015,971

~~Balances~~Gains ~~related~~recognized tofor the ~~contracts~~quarters ended April 30, 2010 and 2009, to adjust the above derivative liabilities to fair value are included on the ~~balance~~statements ~~sheets~~of operations atunder ~~October~~the 31caption “Changes in fair value of liability,” ~~2009~~among items of other income and ~~January~~expense. The ~~31,~~gains ~~2010,~~and (losses) are composed of changes to the liabilities as follows:

	January 31, 2010		October 31, 2009
	April 30, 2010		April 30, 2009
Conversion features	$	~~444~~251,~~298~~572	$	~~585~~205,~~182~~485
Warrant liabilities		326,388		430,789
Warrant Liabilities		423,615		121,942
Derivative Liability	$	770,686	$	1,015,971
Gain	$	675,187	$	327,427

Gains recognized for the quarters ended January 31, 2010 and 2009, to adjust the above derivative liabilities to fair value are included on the statements of operations under the caption "Changes in fair value of derivative liability," among items of other income and expense. The gains and (losses) are composed of changes to the liabilities as follows:

	January 31, 2010		January 31, 2009
Conversion features	$	140,884	$	(24,772	)
Warrant liabilities		104,401		(41,513	)
Gain (Loss)	$	245,285	$	(66,285	)

(7) Fair Value Measurements

~~SFAS No. 157,~~Topic 820, Fair Value Measurements and Disclosures, ~~primarily~~establishes ~~codified under Topic 820, established~~ a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value. These tiers include: Level 1, defined as observable inputs such as quoted prices in active markets; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions. As of ~~January 31~~April 30, 2010, our stock warrant liability lack Level 1 and 2 inputs and are thus required to be measured at fair value on a Level 3 basis.

10The fair value of stock warrant liabilities is the estimated present value at grant date using the Black-Scholes option-pricing model with the following weighted average assumptions for October 31, 2009 and April 30, 2010: expected volatility of 158% and 60% respectively, a risk-free interest rate of 4.00% respectively; and an expected option life remaining from 2.5 to 5 years respectively.

(8) Exploration Stage

Since its inception, the Company has devoted substantially all of its efforts to acquiring operating assets, business planning, raising capital, drilling and exploration. However, on October 23, 2009, the Company completed preparation and connected into the pipeline system operated by Seminole Energy Services. With connection, the Company now has a viable method of delivery of its natural gas product, and sales began in the first quarter of fiscal year 2010. Accordingly, the Company is considered to have then left the exploration stage.

Kentucky USA Energy, Inc.

Notes to Condensed Financial Statements

(Unaudited)

(79) ~~Fair Value Measurements~~Subsequent ~~(continued)~~Events

On May 21, 2010, the Company received a letter from legal counsel representing K&D Energy and each of the landowners/lessors (the “Lessors”) of the nine leases of which the K&D Leasehold is comprised. The ~~fair~~letter claims the ~~value~~Company is in default of ~~stock~~its ~~warrant~~obligations ~~liabilities~~under the Farm-Out Agreement. Specifically, the letter claims the Company is not paying K&D Energy and the ~~estimated~~Lessors ~~present~~the ~~value~~correct atamount ~~grant~~of ~~date~~royalties due them on the ~~using~~sale of gas pumped from the ~~Black~~wells on the K&D Leasehold; the Company has not drilled the minimum of 12 wells per year required under the Farm-~~Scholes~~Out ~~option~~Agreement and that, therefore, the Company’s rights and interests under the Farm-~~pricing~~Out ~~model~~Agreement, except with respect to the ~~following~~wells ~~weighted~~that ~~average~~already have been drilled and completed, ~~assumptions~~are ~~for~~terminated; ~~October~~that 31if the proper amount of royalties is not paid with respect to the wells that already have been drilled and completed, ~~2009~~the Company will lose all rights to and ~~2010:~~interests ~~expected~~in ~~volatility~~those wells and the Farm-Out Agreement shall be deemed terminated with respect to those wells; that the Company is in breach of certain ~~158%~~duties to repair damages on the leased properties caused by its drilling efforts; and ~~158%~~that, with respect to the design and construction of its pipeline ~~respectively~~gathering system, athe ~~risk-free~~Company ~~interest~~is ~~rate~~in breach of ~~4.00%~~certain ~~respectively;~~local safety regulations and ancertain ~~expected~~state law requirements relating to the obtaining of required ~~option~~licenses ~~life~~and ~~remaining~~permits and has failed to obtain certain right-of-way easement agreements from 2certain of the Lessors.5 The toCompany 5strongly ~~years~~denies these ~~respectively~~allegations and will defend its rights under the Farm-Out Agreement vigorously. Management believes that the eventual resolution of this matter will not have a material effect on the Company’s financial position or the results of its operations.

~~(8) Exploration Stage~~10

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

Statement Regarding Forward-Looking Information

This report contains forward-looking statements. All statements other than statements of historical facts included in this Quarterly Report on Form 10-Q, including without limitation, statements in this Management’s Discussion and Analysis of Financial Condition and Results of Operations regarding our financial position, estimated working capital, business strategy, the plans and objectives of our management for future operations and those statements preceded by, followed by or that otherwise include the words “believe”, “expects”, “anticipates”, “intends”, “estimates”, “projects”, “target”, “goal”, “plans”, “objective”, “should”, or similar expressions or variations on such expressions are forward-looking statements. We can give no assurances that the assumptions upon which the forward-looking statements are based will prove to be correct. Because forward-looking statements are subject to risks and uncertainties, actual results may differ materially from those expressed or implied by the forward-looking statements. There are a number of risks, uncertainties and other important factors that could cause our actual results to differ materially from the forward-looking statements, including, but not limited to, the availability and pricing of additional capital to finance operations, including the drilling of our initial gas wells, longer term drilling programs and additional leasehold acquisitions, the viability of the shale gas fields in the Illinois Basin in western Kentucky, our ability to build and maintain a successful operations infrastructure and to effectively drill and develop producing wells, the successful negotiation and execution of cost-effective third-party gas drilling, processing and distribution agreements, the continued commitment of drill rig operators and future economic conditions and the volatility and decreases in energy prices.

Except as otherwise required by the federal securities laws, we disclaim any obligations or undertaking to publicly release any updates or revisions to any forward-looking statement contained in this Quarterly Report on Form 10-Q to reflect any change in our expectations with regard thereto or any change in events, conditions or circumstances on which any such statement is based.

Background

Kentucky USA Energy, Inc. (the “Company” or “we”) was incorporated in the State of Delaware on September 29, 2006 under the name Las Rocas Mining Corp. On October 26, 2007, the Company changed its name to Kentucky USA Energy, Inc. to facilitate the merger discussions with KY USA Energy, Inc. (“KY USA”). On May 2, 2008, the Company, KY Acquisition Corp., a wholly-owned subsidiary of the Company (“Acquisition Sub”), and KY USA entered into an Agreement and Plan of Merger and Reorganization (the “Merger Agreement”), which closed on May 2, 2008. Pursuant to the terms of the Merger Agreement, Acquisition Sub merged with and into KY USA, which became a wholly-owned subsidiary of the Company (the “Merger”).

1211

KY USA was incorporated in the Commonwealth of Kentucky on October 5, 2007 to acquire, explore and develop oil and gas resource properties, with a primary focus initially on shale gas in the Illinois Basin in western Kentucky. Through the execution of a Farm-Out Assignment Agreement with K&D Energy, a Kentucky partnership (“K&D Energy”), as supplemented and corrected (the “Farm-out Agreement”), KY USA has secured a 75% net revenue interest, less a 6% overriding royalty interest owned by NSES, LLC., from K&D Energy in a leasehold in Western Kentucky covering approximately 3,000 acres targeting gas extraction from the New Albany Shale (the “K&D Leasehold”). We have identified approximately 40-50 drilling locations on the K&D Leasehold. Our net recoverable “proved developed producing reserves1” on the K&D Leasehold as of October 31, 2009, are estimated at 1.825 billion cubic feet of gas (“Bcf”)2, while “proved undeveloped primary reserves3” are estimated at 23.725 Bcf, for a total proved developed and undeveloped reserves of 25.550 Bcf. The K&D Leasehold is directly adjacent to third-party producing wells.

Well Development Status

~~Following~~We have drilled 18 wells to date to total depths (“TD”) from 2,340 to 3,460 feet in the New ~~closing~~Albany shale formation on our K&D Leasehold. Fifteen (15) of these wells are on the ~~Offering~~K&D Leasehold, two (~~discussed~~2) are on the Additional TPE Acreage (defined below), weand ~~began~~one ~~drilling~~(1) ~~activities~~is ~~at our~~on ~~initial~~the ~~well~~Hardison ~~locations~~Leasehold (defined below). WeThese wells have ~~continued~~been ~~these~~logged, ~~drilling~~cased ~~efforts~~with 4 ½" production ~~using~~casing ~~the~~and ~~net~~cemented, ~~proceeds~~and ~~from~~all ~~our~~but ~~Initial~~three ~~Loan~~of the wells have been perforated and fractured ~~Installment~~and ~~Loans~~all ~~under~~but five have been tested. We utilize nitrogen fracturing of the shale formation to create open spaces for the gas to escape ~~Credit~~and ~~Facility~~have ~~(discussed~~not, ~~below)~~to this point, encountered any water in our formations.

WeThe ~~have~~chart ~~drilled~~below 17shows ~~initial wells to date to total depths (“TD”) from 2,340 to 3,460 feet in~~ the ~~New~~ ~~Albany~~progress ~~shale~~we ~~formation on our K&D Leasehold. These wells~~ have ~~been~~made ~~logged,~~at ~~cased~~our ~~with~~initial ~~4 ½" production casing and cemented, and in all but four cases the~~ wells ~~have been perforated~~, ~~fractured~~as ~~and tested. We utilize nitrogen fracturing~~ of ~~the~~June ~~shale formation to create open spaces for the gas to escape and have not~~15, ~~to this point, encountered any water in our~~ ~~formations~~2010.

We have recently staked out locations for the drilling of a number of additional wells on our K&D Leasehold. We have identified these drilling prospects through recent data analysis and we expect to begin drilling these additional wells during the next few months, as permitting is approved.

Well Name

Drilling Order

Spud-ded

Logged

Casing

Cement

Perf’ed

Frac’ed

4Pt

Test

CR1

Selling

Gas2

Francis Grace # 1

2626’

Yes

Hunter Wells # 3

2509’

2nd phase

Hunter Wells # 2

2340’

3rd phase

B. Johnston # 1

2387’

Yes

Slinker # 1B

2340’

Yes

Walker #1

2430’

2nd phase

Hunter Wells #1

2431’

3rd phase

Francis Grace #2

2395’

3rd phase

J Johnston #24

3011’

10.

Francis Grace #3

2578’

3rd phase

11.

Golden Eagle #1

2760’

Yes

12.

Hunter Wells #4

2721’

3rd phase

We have entered into a contract with an independent drilling company based in western Kentucky for the drilling of an initial 20 wells. This company has committed to drill an additional 20 wells once the first 20 wells have been completed.

The Sale of our Natural Gas

On October 19, 20094, we entered into a base contract for the purchase and sale of natural gas (the “Base Contract”) with Seminole Energy Services, L.L.C. (“Seminole”), one of the largest natural gas distributors in the Oklahoma, Kansas and Texas panhandle region. Pursuant to the terms of the Base Contract, Seminole has agreed to purchase from us up to a maximum of 2,500 mBTU’S (million British thermal units) per day out of the production of gas from our wells on our leasehold properties located in the western Kentucky region.

1 According to Securities and Exchange Commission (“SEC”) definitions, “proved developed reserves” are those that are expected to be recovered from existing wells with existing equipment and operating methods.

2 As determined by Robinson Engineering & Oil Co., Inc., an independent petroleum engineering firm in a report to us dated January 26, 2010.

3 According to SEC definitions, “proved undeveloped reserves” are those that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required.

Well Name

Drilling Order

Spud-ded

Logged

Casing

Cement

Perf’ed

Frac’ed

4Pt

Test

CR1

Selling

Gas2

13.

J Johnston #4

2500’

Yes

14.

B. Johnston #2

2640’

2nd phase

15.

Slinker #2

2618’

Yes

16.

Jackson #1

2664’

17.

Swinney #1

3460’

18.

Hardison #1

2528’

1.	Indicates that Completion Report has been completed and submitted to the state oil and gas authority.

2.	A “Yes” indicates that gas is currently being sold to Seminole from these wells. “2nd phase” and “3rd phase” indicates that the sale of gas from these wells will be phased in in two stages as certain required work on these wells is completed during the fiscal quarter ending July 31, 2010.

3.	This well needs to be re-cemented prior to perfing and fracing.

4.	In the J & J Johnston #2 well, commercial gas was encountered in the Clear Creek Lime which is 60 feet below the New Albany Shale formation. This find was unexpected and will contribute to the production of this well.

We have staked out locations for the drilling of a number of additional wells on our K&D Leasehold, as listed in the chart below. We have identified these drilling prospects through recent data analysis, and subject to amicable resolution of the dispute with K&D ownership, we expect to begin drilling these additional wells during the next few months, as permitting is approved.

Well Name		Drilling Permit Granted
Walker #2		X
J & J Johnston #1
Golden Eagle #2
B. Johnston #3		X
Hunter Wells #5
Lacefield-Taylor #1		X
Lacefield-Taylor #2
Slinker #3B

The Sale of our Natural Gas

On October 19, 20094, we entered into a base contract for the purchase and sale of natural gas (the “Base Contract”) with Seminole Energy Services, L.L.C. (“Seminole”), one of the largest natural gas distributors in the Oklahoma, Kansas and the Texas panhandle region. Pursuant to the terms of the Base Contract, Seminole has agreed to purchase from us up to a maximum of 2,500 mBTU’S (million British thermal units) per day out of the production of gas from our wells on the K&D Leasehold.

4 As more fully discussed in our Form 8-K filed with the SEC on October 23, 2009.

We will sell our gas to Seminole following treatment and purification of the gas at Seminole’s gathering and treatment facilities located in Christian and Muhlenberg Counties, Kentucky. This facility is jointly owned by Seminole and Daugherty Petroleum, Inc., and is managed by Seminole. We have constructed approximately 67,000 feet of gathering line to connect our wells to Seminole’s gathering and treatment facility. We completed this system of lines and the interconnection to Seminole’s gathering facility in October 2009. ~~Fourteen~~ Fifteen (1415) of our wells are now ~~connected~~tied-in to this system.

Seminole will pay us the Gas Daily Texas Zone SL daily midpoint spot price for the gas that it purchases from us. We and Seminole have agreed to net any payments due us under the Base Contract against fees due Seminole under that certain Gas Gathering & Treatment Agreement between the Company and Seminole (and its related parties) dated August 6, 20095.

On October 27, 2009, we began the production and delivery of natural gas to Seminole’s treatment facilities, with actual sales beginning in November 2009. We are now selling gas to Seminole from six (6) of our wells that are connected to the Seminole facility and we expect to begin selling gas from an additional eight wells in two phase-ins during the fiscal quarter ending July 31, 2010. The remaining wells will be brought on line as soon as funds become available to complete necessary pipeline and/or tie-in work.

~~The~~Due ~~sale~~to ofbottlenecks ~~our~~at ~~gas~~the to Seminole ~~since~~facility ~~our~~created ~~tie-in~~as toa ~~the~~result ~~Seminole~~of ~~gathering~~the ~~and~~increased ~~processing~~gas ~~facility~~volume ~~has~~flowing ~~been~~from ~~minimal,~~our ~~however,~~wells ~~and~~into the ~~flow~~facility, the sale of our gas ~~into~~to ~~the~~ Seminole ~~facility~~since ~~has~~our ~~been~~tie-in ~~intermittent, due~~ to athe ~~bottleneck~~Seminole atgathering ~~the~~and ~~Seminole~~processing facility has been ~~created~~minimal asand athe ~~result~~flow of ~~the~~our ~~increased~~ gas ~~volume~~into ~~flowing~~the ~~from~~Seminole ~~our~~facility ~~wells~~has ~~into the~~been ~~facility~~intermittent. Because of the potential increased sales volume expected from our wells, Seminole has ~~been~~added ~~adding~~ new equipment to its facilities to ~~increase~~ increase efficiencies and improve Seminole’s ability to accept ~~our~~and process our natural gas ~~into its facility~~. ~~During~~We ~~the final wrap-up stages of completing the facility upgrade, we~~ are working with Seminole to balance the system and maximize our production and delivery of our gas to the facility. We expect to increase the rate of ~~its~~ production and delivery of our gas to Seminole during the ~~current~~next few fiscal ~~quarter~~quarters ~~following completion~~as ofwe ~~the~~bring ~~facility~~additional ~~upgrade~~wells online.

Thomasson Farm-Out and 7921 Energy Joint Venture

On August 24, 2009, KY USA entered into a farm-out agreement with Thomasson Petroleum Enterprises, Inc. (“TPE”) to acquire from TPE certain drilling rights on farm-out acreage (the “Additional TPE Acreage”) in Todd, Muhlenberg and Christian counties in western Kentucky adjacent to the Company’s existing K&D Leasehold (the “TPE Farm-Out Agreement”). Under the terms of of the ~~agreement~~TPE ~~with~~Farm-Out ~~TPE~~Agreement, KY USA acquired the right to drill up to 40 wells on the ~~subject~~Additional ~~leases~~TPE Acreage to explore for oil and gas in, above and below the New Albany Shale. KY USA must drill ten (10) wells in each year of the agreement to be eligible to drill an additional ten wells in the following year, up to a maximum of 40 wells over four years. TPE will retain a 25% net revenue interest in the wells that KY USA drills into the Albany shale on the Additional TPE ~~acreage~~Acreage and an 18.75% net revenue interest in any oil “twin wells” drilled above the top of the Albany shale.

5 As more fully discussed in our Form 8-K filed with the SEC on August 17, 2009.

In August 2009, KY USA ~~recently~~ entered into a joint venture (“JV”) agreement with 7921 Energy LLC (“7921”) to develop natural gas and oil prospects in, above and below the New Albany Shale formation on the Additional TPE ~~acreage~~Acreage. The wells to be drilled under the JV agreement will utilize the Company’s field gathering system that is ~~currently~~ currently connected to the Olive Grove Treatment Facility. Under the terms of the JV agreement, 7921 will have the right to participate with KY USA in in drilling and developing up to 40 wells on the newly acquired ~~TPE~~Additional ~~farm-out~~TPE ~~acreage~~Acreage. Phase 1 under this JV agreement will consist of drilling and completing ten (10) wells. Under the terms of the JV, 7921 will earn a 50% working interest in each of the first ten wells, which translates to a 37.5% net revenue interest (assuming each well is funded by 7921 and drilled to completion), in exchange for providing KY USA with $1,675,000 in working capital to drill and complete the Phase 1 wells. The 50% working interest is reduced by a 6% overriding royalty interest owned by NSES, LLC. 7921 will also retain the option to participate with KY USA in the drilling of the up to 30 additional wells on the Additional TPE ~~acreage~~Acreage. ToBecause ~~date~~7921 ~~the Company~~ has not ~~received~~yet made any payments to us under the ~~indicated~~JV ~~payment~~agreement, ~~and~~we ~~no transactions~~have ~~are~~elected ~~reflected~~not onto ~~the~~give ~~Company’s~~accounting ~~financial~~recognition to the ~~statements~~transaction as aof ~~result~~April of30, 2010. At this time, we cannot be sure that 7921 will proceed with payments to us under the JV agreement.

Thomasson - Hardison Lease Farm-Out

Effective January 21, 2010, KY USA entered into a farm-out agreement with TPE (the “TPE/Hardison Farm-Out Agreement”) to acquire from TPE certain drilling rights on TPE’s leasehold acreage under the Linda Hardison lease (the “Hardison Leasehold”) in Todd County in western Kentucky adjacent to our existing K&D Leasehold. Under the terms of the TPE/Hardison Farm-Out Agreement, KY USA acquired the right to drill wells below the top of the Devonian (Black) shale formation on the Hardison ~~leasehold~~ Leasehold. We are required to pay TPE $20,000 for each well location and we have paid TPE an initial $20,000 for the first well that we ~~will~~have ~~be drilling~~drilled, the Hardison #1 well.

We have completed drilling the ~~first well on the~~ Hardison ~~acreage, tha Hardison~~ #1 well, and reached total depth at 2,412 feet. The well has been evaluated and determined to be commercially viable - the Hardison #1 well’s drilling log confirms that there is approximately 155 feet of black shale formation encountered in this well. WeThe ~~have begun the completion process on the~~ Hardison #1 well ~~and 4 ½” production casing~~ has been ~~run~~perforated, ~~into~~fractured ~~the~~and ~~well.~~completed, Weand ~~have~~is ~~also~~ready ~~scheduled perforation~~for ~~and~~tie-in ~~fracing~~to Seminole’s ~~of this well~~facility.

If the Hardison #1 well proves to be a producing well, we will have the right to continue to develop this leasehold by drilling a minimum of one well per year until the leasehold is completely developed. We will receive our assigned rights under the TPE/Hardison Farm-Out Agreement once we have completed the first producing well and have met certain other terms under the ~~farm-out~~TPE/Hardison ~~agreement~~Farm-Out Agreement. Under the assignment, we shall be entitled to a seventy-five percent (75%) net revenue working interest, less a 6% overriding royalty interest in each producing well that we develop on ~~this~~the Hardison ~~leasehold~~Leasehold. To drill under this agreement, TPE is requiring that we remain in compliance with the terms and conditions of the TPE Farm-Out Agreement.

Results of Operations for the Three and Six Month Periods Ended ~~January~~April 3130, 2010 and 2009

Revenues

We are still in our exploration stage and have generated minimal revenue to date.

We generated $32,360 in revenues for the three month period ended January 31, 2010 compared to no revenues for the three month period ended January 31, 2009. This change was the result of our beginning to sell our initial well production to Seminole under the Base Contract.

~~All~~We ~~productive~~generated ~~and non-productive costs incurred in connection with the acquisitions of~~$61,278 ~~exploration for~~ and ~~development of our gas reserves are capitalized using the full cost method of accounting. These costs include lease acquisitions~~$93,638 ~~geological~~in ~~and~~revenues ~~geophysical~~for ~~work, and~~ the ~~costs~~three ~~of drilling, completing~~ and ~~equipping~~six ~~our gas wells. For the three~~ month periods ended ~~January~~April 3130, 2010 ~~and 2009~~, ~~we incurred such capitalized costs of $405,542 and $71,550,~~ respectively. The increase from 2009 to 2010 was the result of loan fees capitalized related to additional borrowing used to facilitate additional drilling. We incurred currently expensed production costs and taxes related to our well production in the three month period ended January 31, ~~2010 of $29,836~~ compared to no ~~costs~~revenues ~~in this category~~ for the three ~~month~~and ~~period~~six month periods ended ~~January~~April 3130, 2009,. This aschange awas the result of our ~~having~~beginning ~~begun~~to ~~the~~sell our initial ~~sales of~~well ~~our~~production ~~gas~~ to Seminole inunder the ~~three month period ended January 31,~~Base ~~2010~~Contract.

WeCosts ~~incurred general~~ and administrative expenses of $37,001 and $42,622 for the three month periods ended January 31, 2010 and 2009, respectively. These expenses consisted of costs incurred in connection with the start-up and day to day operation of our business.Expenses

~~Amortization~~All ofproductive ~~loan~~and ~~fees~~non-productive costs incurred in connection with the acquisitions of, exploration for and development of our gas reserves are capitalized using the full cost method of accounting. These costs include lease acquisitions, geological and geophysical work, and the costs of drilling, completing and equipping our gas wells. For the three month periods ended ~~January~~April 3130, 2010 and ~~January~~2009, 31we incurred such capitalized costs of $590,553 ~~2009~~and ~~totaled~~ $911,~~099~~841,676, inrespectively. For ~~each~~the six month periods ended April 30, 2010 and 2009, we incurred such ~~period~~total capitalized costs of $1,009,084 and $2,696,768, respectively. ~~These~~The decreases from 2009 to 2010 were the result of decreases in costs ~~are~~and spending related to our drilling program. More specifically, the ~~Note~~decrease ~~and~~from 2009 to 2010 was the result ~~Loan~~of ~~(discussed~~a ~~below)~~decrease of loan fees capitalized related to additional borrowing used to facilitate additional drilling.

~~Legal~~We incurred currently expensed production costs and ~~professional~~ ~~expenses~~taxes ~~increased~~related to ~~$76,203~~our ~~for~~well production in the three and six month ~~period~~periods ended ~~January~~ 31April 30, 2010 ~~from~~of $3644,~~907~~829 and $74,665, respectively, compared to no costs in this category for the three and six month ~~period~~periods ended ~~January~~April 3130, 2009~~. The~~, ~~increase~~as ina ~~these~~result ~~expenses~~of ~~primarily~~our ~~resulted~~having ~~from~~begun the initial ~~costs~~sales ~~relating~~of our gas to ~~increased~~ ~~activity~~Seminole in ~~legal~~the ~~fees~~six ~~associated~~month ~~with~~period ~~contracts~~ended ~~being~~April ~~drawn~~30, up2010.

~~Our~~We ~~interest~~incurred ~~expense~~general and administrative expenses of $26,413 and $23,704 for the three month periods ended ~~January~~April 3130, 2010 and 2009, ~~was~~ ~~$71~~respectively,~~550~~ and $7452,~~137~~491 ~~respectively. This cost is attributable to interest due~~ and ~~paid on the Note and the Loan~~ $66,327 asfor ~~well as non-cash amortization of~~ the ~~note discount.~~six ~~During the three~~ month ~~period~~periods ended ~~January~~April 3130, 2010, weand ~~recognized~~2009, arespectively. ~~net~~These ~~gain~~expenses onconsisted aof ~~derivative~~costs ~~liability~~incurred ~~relating~~in toconnection ~~the~~with ~~Note in~~ the ~~amount~~start-up ofand ~~$245,285,~~day ~~due~~ to aday ~~revaluation~~operation of ~~the~~our ~~derivative liability to market at January 31, 2010~~business.

~~Liquidity~~Amortization of loan fees for the three month periods ended April 30, 2010 and ~~Capital~~April 30, 2009 ~~Resources~~totaled $91,099 in each such period, and $182,198 for each six month period ended April 30, 2010 and 2009. These costs are related to the Note and the Loan (discussed below).

~~Our~~Compensation expense ~~cash~~decreased to $105,200 for the three month period ended April 30, 2010 from $322,500 for the three month period ended April 30, 2009, and ~~cash~~decreased ~~equivalents~~to $212,259 ~~balance~~for asthe ofsix ~~January~~month 31period ended April 30, 2010 ~~was~~from $~~477~~670,~~487~~198 for the six month period ended April 30, 2009. These expenses relate to stock option and warrant costs.

OnLegal and ~~May 9,~~professional ~~2008,~~expenses KYdecreased ~~USA~~to ~~borrowed~~ $~~100~~58,~~000~~009 ~~from~~for ~~one~~the ~~individual~~three asmonth aperiod ~~bridge loan~~ended toApril be30, ~~used~~2010 ~~for~~from ~~working capital purposes. In addition~~$63,855 ~~upon~~for the ~~closing~~three ofmonth ~~the Merger,~~period ~~this~~ended ~~lender~~April ~~received~~30, ~~warrants~~2009, but increased to ~~purchase 200~~$134,~~000~~032 ~~shares~~for ofthe ~~our~~six ~~Common Stock,~~month ~~such~~period ~~warrants~~ended ~~having~~April an30, ~~initial~~2010 ~~exercise~~from $100,762 ~~price~~for ofthe ~~$1.00~~six ~~per~~month ~~share~~period ~~and expiring~~ended ~~five~~April ~~years~~30, ~~after issuance~~2009.

Our interest expense for the three month periods ended April 30, 2010 and 2009 was $74,194 and $205,169, respectively, while for the six month periods ended April 30, 2010 and 2009, these expenses totaled $145,745 and $279,305, respectively. This cost is attributable to interest due and paid on the Note and the Loan, as well as non-cash amortization of the note discount. These decreases were due to a reduction in the non-cash amortization for these periods.

~~On May~~During ~~29, 2008 we closed a private offering (~~the ~~“Offering”)~~three ~~of an 8% senior secured convertible note (the “Note”)~~ and ~~warrants~~six ~~(the~~month ~~“Warrants”)~~periods toended ~~purchase 2~~April 30,~~500,000~~ ~~shares of the Company’s common stock~~2010, ~~$0.0001~~we ~~par~~recognized ~~value~~a ~~per~~net ~~share (the~~gain ~~“Common~~on ~~Stock”),~~a toderivative ~~one~~liability ~~institutional~~relating ~~investor~~to (the ~~“Investor”)~~Note ~~for~~in ~~aggregate gross~~the ~~proceeds~~amounts of $~~2.5 million~~675,187 ~~as more fully described in our Form 8-K filed~~and ~~with the SEC on June 4~~$ 920,472, respectively, ~~2008. We~~while ~~have~~these ~~used~~amounts ~~the~~for ~~net proceeds of~~ the ~~Offering~~ ofthree ~~approximately~~and ~~$1,857,600~~six ~~(after~~month ~~expenses~~periods ~~of the Offering) to repay~~ended ~~bridge~~April ~~loans made to KY USA~~30, to2009 ~~begin~~totaled ~~drilling our initial wells~~$327,427 and ~~for general~~$261,143, ~~working capital purposes~~respectively. These gains ~~The~~were ~~initial~~due ~~installment~~to ~~payment~~a ~~date~~revaluation onof the ~~Note~~ ~~was~~derivative ~~extended~~liability ~~from~~to ~~May~~market ~~29,~~at ~~2009~~the toend of ~~May~~each ~~29,~~applicable ~~2010~~period.

~~On June~~Net 27, 2008, KY USA, entered into a credit agreement (the “Credit Agreement”) with NSES 12, LLC (the “Lender”), a funding vehicle of New Stream Capital, pursuant to which KY USA may borrow up to $10,000,000 in the aggregate, under certain conditions (the “Loan”). Under the Loan, KY USA initially borrowed $2,500,000 (the “Initial Loan”), and may borrow up to an additional aggregate amount of $7,500,000 in installments of a minimum of $2,500,000 (or such lesser amounts as the Lender may approve) each (each, an “Installment Loan”), solely at the discretion of the Lender. The proceeds of the Initial Loan, net after expenses of the transaction, including a $200,000 credit facility fee paid to the Lender and a $200,000 consulting fee paid to one consultant at closing, were used by KY USA for ongoing working capital purposes, including the costs and expenses relating to the drilling of our initial wells in the New Albany shale on the K&D Leasehold. The term note evidencing the Loan was issued pursuant to the exemption from the registration requirements of the federal securities laws provided by Section 4(2) of the Securities Act. No sales commissions were paid in connection with the Initial Loan.Loss

OnOur net ~~February~~income ~~12,~~for ~~2009,~~the wethree ~~received~~and ~~the~~six ~~first~~months ~~Installment~~ended ~~Loan~~April in30, an2010 ~~amount~~was of $~~2.5~~322,960 and ~~million~~$185,236, onrespectively, ~~August~~compared 14to losses of $(378,900) ~~2009~~and $(1,037,647), respectively, wefor ~~received~~the athree ~~second~~and ~~Installment~~six ~~Loan~~months ofended ~~$600~~April 30,~~000~~ 2009. The ~~and~~increases onin ~~December~~income ~~11,~~from 2009, weto ~~received~~2010 anare ~~additional~~mainly ~~Installment~~due ~~Loan~~to ofdecreases ~~$1.2~~in our ~~million. To~~operating ~~date,~~costs weover ~~have~~these ~~received~~periods ~~$6,850,000~~attributable ~~under~~to a decrease in compensation expenses and adjustments to the ~~Credit~~estimated fair value of our derivative ~~Facility~~liabilities.

~~The~~Adjusted ~~Credit~~EBITDA Agreement requires that KY USA comply with financial covenants relating to, among other things, collateral and current ratio coverage. As of January 31, 2010, KY USA was not in compliance with the 1.0 to 1.0 current ratio requirement of the Credit Agreement. This breach of the current ratio covenant contained in the Credit Agreement constitutes an event of default under the Credit Agreement. The breach would permit the Lender under the Credit Agreement to declare all amounts borrowed thereunder to be immediately due and payable. We intend to request from the Lender a waiver of this current ratio covenant, but we cannot assure you that we will be successful in obtaining such waiver. Additionally, even if we obtain a waiver from the Lender, we may not be able to satisfy these or other covenants in the future or be able to pursue our strategies within the constraints of these covenants. These circumstances could materially and adversely impair our liquidity and, among other factors, raise substantial doubt regarding our ability to continue as a ~~going~~Non-GAAP ~~concern.~~Performance Measure

OnIn evaluating ~~July~~our business, management believes earnings before interest, 22amortization of financing costs, ~~2009~~taxes, KYdepreciation, ~~USA~~depletion, ~~entered~~amortization and ~~into~~accretion ~~the~~of JVabandonment ~~agreement~~liabilities, ~~with~~unrealized ~~7921~~gains ~~pursuant~~and tolosses ~~which~~on financial ~~7921~~instruments, gains and losses on sales of assets and stock-based ~~agreed~~compensation toexpense ~~provide~~("Adjusted KYEBITDA") ~~USA~~is ~~with~~a ~~$1,675,000~~key inindicator ~~working~~of ~~capital~~financial operating performance and is a measure of our ability to generate cash for operational ~~the~~activities ~~Phase~~and 1future capital expenditures. Adjusted ~~drilling~~EBITDA is not a GAAP measure of ~~the~~performance. ~~first~~We 10use ~~wells~~this onnon-GAAP ~~the~~measure primarily ~~TPE~~to ~~acreage~~compare our performance with other companies in our industry and as a measure of our current liquidity. ~~These~~We ~~funds~~believe that this measure may ~~not~~also be ~~used~~useful to investors for ~~any~~the ~~other~~same ~~purpose~~purposes and ~~are~~as toan beindication ~~disbursed~~of our ability to KYgenerate ~~USA~~cash onflow at a ~~well~~level ~~by well~~that ~~basis~~can ~~prior~~sustain toor ~~the~~support ~~drilling~~our operations ofand acapital ~~particular~~investment ~~well~~program. ~~Under~~Investors ~~terms~~should ofnot ~~the~~consider ~~agreement,~~this anmeasure ~~initial~~in ~~payment~~isolation ofor ~~$50~~as a substitute for income from operations,~~000~~ ~~was~~or tocash beflow ~~provided~~from tooperations usdetermined ~~by September~~under 30GAAP, ~~2009.~~or Toany ~~date~~other measure ~~the~~for ~~Company~~determining ~~has~~operating ~~not~~performance ~~received~~that ~~the~~is ~~indicated~~calculated ~~payment,~~in accordance ~~and~~with noGAAP. In ~~transactions~~addition, ~~are~~because ~~reflected~~Adjusted onEBITDA ~~the~~is ~~Company’s~~not ~~books~~a asGAAP measure, ait ~~result~~may ofnot ~~this~~necessarily be comparable to similarly titled measures that ~~agreement~~may be disclosed by other companies.

The following is a reconciliation of our net loss in accordance with GAAP to our Adjusted EBITDA for the three and six month periods ending April 30, 2010 and 2009:

	Three months ended						Six months ended
	April 30, 2010			April 30, 2009			April 30, 2010			April 30, 2009

Net Income (loss)	$	322,960		$	(378,900	)	$	185,236		$	(1,037,647	)

Add Back:

Interest expense, net		74,194			205,169			145,745			279,305
Amortization of deferred financing costs		91,099			91,099			182,198			182,198
Income tax expense		-			-			-			-
Depreciation, depletion, accretion and impairment		13,761			-			27,484			-
(Gain) loss on change in derivative value		(675,187	)		(327,427	)		(920,472	)		(261,143	)
(Gain)/loss on sales of assets		-			-			-			-
Stock based compensation		19,250			226,500			40,991			457,000

Adjusted EBITDA	$	(153,923	)	$	(183,559	)	$	(338,818	)	$	(380,287	)

Liquidity and Capital Resources

Our cash and cash equivalents balance as of April 30, 2010 was $109,212 compared to $59,105 at October 31, 2009.

On May 29, 2008 we closed a private offering of an 8% senior secured convertible note (the “Note”) and warrants to purchase 2,500,000 shares of our common stock to one institutional investor for aggregate gross proceeds of $2.5 million. The Note has been amended to extend the initial installment payment date from May 29, 2010 to May 29, 2011.

On June 25, 2008, KY USA entered into a credit agreement (the “Credit Agreement”) with NSES 12, LLC (the “Lender”), a funding vehicle of New Stream Capital, pursuant to which KY USA may borrow up to $10,000,000 in the aggregate, under certain conditions. To date, we have borrowed $6,850,000 under the Credit Agreement. The Credit Agreement requires that KY USA comply with financial covenants relating to, among other things, collateral and current ratio coverage. As of April 30, 2010, KY USA was not in compliance with the 1.0 to 1.0 current ratio requirement of the Credit Agreement. This breach of the current ratio covenant contained in the Credit Agreement constitutes an event of default under the Credit Agreement. Additionally, because of our limited available cash, we have been in default since March 1, 2010 on our obligation under the Credit Agreement to pay the Lender interest on a monthly basis. Through June 1, 2010, the most recent interest payment date, there was a total of $308,366.90 accrued and unpaid past due interest under the Credit Agreement. These defaults would permit the Lender under the Credit Agreement to declare all amounts borrowed thereunder to be immediately due and payable. We have requested from the Lender a forbearance and waiver of our Credit Agreement defaults, but we cannot assure you that we will be successful in obtaining this. Additionally, even if we obtain a forbearance and waiver from the Lender, we may not be able to satisfy these or other covenants and obligations in the future or be able to pursue our strategies within the constraints of these covenants and obligations. These circumstances could materially and adversely impair our liquidity and, among other factors, raise substantial doubt regarding our ability to continue as a going concern. At this time, we do not know whether KY USA will be able to borrow any additional funds under the Credit Facility.

~~Including~~On July ~~the~~22, ~~net~~2009, ~~proceeds~~KY ~~from~~USA ~~the~~entered ~~Offering,~~into the ~~Credit~~JV ~~Facility~~agreement ~~and~~with ~~the~~ 7921 JVpursuant to which 7921 ~~agreement,~~agreed weto ~~believe~~provide ~~that~~KY weUSA ~~have~~with ~~sufficient~~$1,675,000 ~~funds~~in toworking ~~conduct~~capital ~~our~~for ~~operations~~the Phase 1 ~~for~~drilling ~~approximately~~of the ~~next~~first ~~three~~10 towells ~~six~~on ~~months~~the TPE acreage. To date, ifthe Company has not received any funds under the ~~notes~~7921 ~~are~~JV ~~not~~agreement and there can be ~~called~~no assurance that we will receive any funds from 7921.

If Currently, we ~~are~~ do not ~~successful~~have insufficient ~~generating~~capital ~~sufficient~~to ~~liquidity~~continue ~~from~~our KYdrilling program. We ~~USA~~have ~~operations~~recently orbegun ~~in raising~~to ~~sufficient~~generate ~~capital~~revenues ~~resources~~and oncash ~~terms~~flow from ~~acceptable~~the sale of our gas to ~~us,~~Seminole and we are applying these funds towards our ongoing ~~business~~working capital needs, including well maintenance and production and the ~~results~~bringing of ~~operations,~~additional ~~liquidity~~wells on line to Seminole’s processing and ~~financial~~sales facility. We ~~condition~~expect ~~could~~our ~~suffer~~revenues and cash flow to increase over the ~~materially~~next few quarters as we bring additional wells online.

We presently do not have any available credit, bank financing or other external sources of liquidity, other than the ~~net~~Credit ~~proceeds~~Agreement. ~~from~~We ~~the~~will ~~Offering,~~be ~~the~~able ~~New~~to ~~Stream~~generate ~~Credit~~a ~~Facility~~certain ~~and~~amount ~~7921~~of JVliquidity ~~agreement.~~from ~~Due~~KY USA operations to meet some of our ~~brief~~ongoing ~~history~~operational ~~and~~expenses but we will need to raise additional capital ~~historical~~to, ~~operating~~among ~~losses~~other things, restart our ~~operations~~drilling ~~have~~program, ~~not~~complete ~~been~~pipeline tie-ins for a ~~source~~number of ~~liquidity. We~~our ~~will~~already ~~need~~drilled towells, ~~obtain~~cure ~~additional~~our ~~capital~~interest inpayment ~~order~~default under tothe ~~expand~~Credit ~~operations~~Agreement and ~~become~~ ~~profitable.~~acquire additional exploration and production acreage. In order to obtain additional capital, we may need to sell ~~additional~~ additional shares of our common stock or borrow funds from private lenders. There can be no assurance that we will be successful in obtaining additional funding in amounts or on terms acceptable to us, if at all. If we are not able to raise capital and restart our drilling program, our business, results of operations, liquidity and financial condition will suffer materially.

Critical Accounting Policies

The Company prepares its Consolidated Financial Statements in conformity with accounting principles generally accepted in the United States of America, which requires the Company to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the year. Actual results could differ from those estimates. The Company considers the following policies to be the most critical in understanding the judgments that are involved in preparing the Company’s financial statements and the uncertainties that could impact the Company’s results of operations, financial condition and cash flows.

Full Cost Method of Accounting

The Company follows the full cost method of accounting for oil and gas property acquisition, exploration and development activities. Under this method, all productive and non-productive costs incurred in connection with the acquisition of, exploration for and development of oil and gas reserves for each cost center are capitalized. Capitalized costs include lease acquisitions, geological and geophysical work, day rate rentals and the costs of drilling, completing and equipping oil and gas wells. Costs, however, associated with production and general corporate activities are expensed in the period incurred. Interest costs related to unproved properties and properties under development are also capitalized to oil and gas properties. Gains or losses are recognized only upon sales or dispositions of significant amounts of oil and gas reserves representing an entire cost center. Proceeds from all other sales or dispositions are treated as reductions to capitalized costs. The capitalized oil and gas property, less accumulated depreciation, depletion and amortization and related deferred income taxes, if any, are generally limited to an amount (the ceiling limitation) equal to the sum of: (a) the present value of estimated future net revenues computed by applying current prices in effect as of the balance sheet date (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil and gas reserves, less estimated future expenditures (based on current costs) to be incurred in developing and producing the reserves using a discount factor of 10% and assuming continuation of existing economic conditions; and (b) the cost of investments in unevaluated properties excluded from the costs being amortized. No ceiling write-downs have been recorded to date.

Oil and Gas Reserves

The Company’s proved gas reserves as of October 31, 2009 were developed from information provided by Glenn Robinson – Robinson Engineering. Projecting the effects of commodity prices on production, and timing of development expenditures includes many factors beyond the Company’s control. The future estimates of net cash flows from the Company’s proved reserves and their present value are based upon various assumptions about future production levels, prices, and costs that may prove to be incorrect over time. Any significant variance from assumptions could result in the actual future net cash flows being materially different from the estimates.

Derivative Instruments

We value derivative instruments in accordance with the interpretative guidance of ASC Topic 815 and associated pronouncements related to the classification and measurement of warrants and instruments with embedded conversion features. We make certain assumptions and estimates to value our derivative liabilities. Factors affecting these liabilities and values include changes in the stock price and other assumptions.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements.

ITEM 4T. CONTROLS AND PROCEDURES

EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of our management, including our principal executive officer and principal financial officer, we have conducted an evaluation of the effectiveness of the design and operation of our disclosure controls and procedures, as defined in Rules 13a-15(e) and 15d-15(e) under the Securities and Exchange Act of 1934, as of the end of the period covered by this report. Based on this evaluation, our principal executive officer and principal financial officer concluded as of the evaluation date that, due to the insufficiency of the depth and breadth of our accounting function, our disclosure controls and procedures were not adequate and effective to ensure that our management is alerted to material information required to be included in our periodic filings with the SEC. We are in the process of improving our processes and procedures to ensure full, accurate and timely disclosure in the current fiscal year, with the expectation of establishing effective disclosure controls and procedures as soon as reasonably practicable.

19Changes in Internal Controls over Financial Reporting

~~Additionally,~~There ~~there~~ were no significant changes in our internal controls or in other factors ~~that~~ that could significantly affect these controls subsequent to the evaluation date. We have not identified any significant deficiencies or material weaknesses in our internal controls, and therefore there were no corrective actions taken.

PART II – OTHER INFORMATION

ITEM 5. OTHER INFORMATION.

KY USA has received a letter dated May 21, 2010 from legal counsel to K&D Energy and each of the landowners/lessors (the “Lessors”) of the nine leases of which the K&D Leasehold is comprised. The letter claims that that KY USA is in default of its obligations under the Farm-Out Agreement. Specifically, the letter claims that KY USA is not paying K&D Energy and the Lessors the correct amount of royalties due them on the sale of gas pumped from the wells on the K&D Leasehold; that KY USA has not drilled the minimum of 12 wells per year required under the Farm-Out Agreement and that, therefore, KY USA’s rights and interests under the Farm-Out Agreement, except with respect to the wells that already have been drilled and completed, are terminated; that if the proper amount of royalties is not paid with respect to the wells that already have been drilled and completed, KY USA will lose all rights to and interests in those wells and the Farm-Out Agreement shall be deemed terminated with respect to those wells; that KY USA is in breach of certain duties to repair damages on the leased properties caused by its drilling efforts; and that, with respect to the design and construction of its pipeline gathering system, KY USA is in breach of certain local safety regulations and certain state law requirements relating to the obtaining of required licenses and permits and has failed to obtain certain right-of-way easement agreements from certain of the Lessors. We and KY USA strongly deny these allegations and will defend our rights under the Farm-Out Agreement vigorously. Additionally, we believe that case law in the State of Kentucky supports our position that net revenue interest royalties should be paid on the net amount of gas pumped from our wells after the removal of inert materials and other impurities rather than on the gross amount of gas measured at the well head prior to processing.

ITEM 6. EXHIBITS.

Exhibit No.		Description
10.1		Farm-Out Agreement by and between Thomasson Petroleum Enterprises, Inc. and KY USA Energy, Inc. dated January 21, 2010 (1)
31.1		Certification of Principal Executive Officer pursuant to Section 302 the Sarbanes-Oxley Act of 2002
31.2		Certification of Principal Financial Officer pursuant to Section 302 the Sarbanes-Oxley Act of 2002
32.1		Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002*
32.2		Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002*

* This certification is being furnished and shall not be deemed “filed” with the SEC for purposes of Section 18 of the Exchange Act, or otherwise subject to the liability of that section, and shall not be deemed to be incorporated by reference into any filing under the Securities Act or the Exchange Act, except to the extent that the Registrant specifically incorporates it by reference.

(1) Filed with the Securities and Exchange Commission (the “SEC”) on February 16, 2010 as an exhibit to the Registrant’s Annual Report (SEC File No. 333-141480) on Form 10-K, which exhibit is incorporated herein by reference21

SIGNATURES

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

Date: March 17, 2010	Kentucky USA Energy, Inc.
Date: June 21, 2010	Kentucky USA Energy, Inc.
	By:	/s/Steven D. Eversole
	Name: Steven D. Eversole	~~Name: Steven D. Eversole~~
	Title: Principal Executive Officer	~~Title: Principal Executive Officer~~
	By:	/s/ Charles M. Stivers
		Name: Charles M. Stivers Title: Principal Financial Officer
	Name: Charles M. Stivers
	Title: Principal Financial Officer

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