U.S. SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-K/A

Amendment No. 1

(Mark One)

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

For Fiscal Year Ended: October 31, 2009

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

For the transition period from _______________ to _______________

Commission file number: 333-141480

Kentucky USA Energy, Inc.
(Exact name of registrant as specified in its charter)

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

321 Somerset Road, Suite 1, London, KY		40741
(Address of principal executive offices)		(Postal Code)

Issuer's telephone number: (606) 878-5987

Securities registered under Section 12(b) of the Act: None

Securities registered under Section 12(g) of the Act: Common Stock, $0.0001 par value

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes ¨ No x

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Exchange Act. Yes ¨ No x

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act 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 ¨

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. x

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a smaller reporting company. See the definitions of the “large accelerated filer,” “accelerate 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 x
(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

As of February 5, 2010, there were 36,927,092 shares of the registrant's common stock, par value $0.0001, issued and outstanding. Of these, 25,883,342 shares are held by non-affiliates of the registrant. The market value of securities held by non-affiliates is $11,129,837, based on the closing price of $0.43 for the registrant’s common stock on April 30, 2009. Shares of common stock held by each officer and director and by each shareowner affiliated with a director have been excluded from this calculation because such persons may be deemed to be affiliates. This determination of officer or affiliate status is not necessarily a conclusive determination for other purposes.

DOCUMENTS INCORPORATED BY REFERENCE

Not Applicable.

EXPLANATORY NOTE

On February 16, 2010, Kentucky USA Energy, Inc. (“Kentucky USA,” the “Company,” “we,” “our” or “us”) filed its Annual Report on Form 10-K for the year ended October 31, 2009 (the “Original Filing”), with the Securities and Exchange Commission (the “SEC”). This Amendment No. 1 (this “Amendment”) on Form-10-K/A, amends and restates Part I, Item 1 (Business”), Item 7 (Management’s Discussion and Analysis of Financial Condition and Results of Operations) and Item 8 (Financial Statements and Supplemental Data).

In addition, as required by Rule 12b-15 of the Securities Exchange Act of 1934, this Form 10-K/A contains new certifications by our principal executive officer and our principal financial and accounting officer, filed as exhibits hereto.

Other than as described above, no changes have been made to any Items included in the Original Filing and this Amendment does not reflect events occurring after the Original Filing or modify or update those disclosures affected by subsequent events. Accordingly, this Amendment should be read in conjunction with the Company’s other filings made with the SEC subsequent to the filing of the Original Filing.

PART I

ITEM 1. BUSINESS

History and General Development of Our Business

Kentucky USA Energy, Inc. was incorporated in the State of Delaware on September 29, 2006 under the name Las Rocas Mining Corp. Our principal business plan was to acquire, explore and develop mineral properties and to ultimately seek earnings by exploiting the mineral claims. We determined that we could not continue with our original business operations because of a lack of financial results and resources and, subsequently, we decided to abandon our mineral property operations and to seek a possible business combination.

On October 26, 2007, we changed our name to Kentucky USA Energy, Inc. to facilitate the merger discussions with KY USA Energy, Inc. (“KY USA”). We also increased our authorized capital stock to an aggregate of 320,000,000 shares consisting of 300,000,000 shares of common stock, $0.0001 par value per share (the “Common Stock”), and 20,000,000 shares of preferred stock with preferences and rights to be determined by our Board of Directors. Additionally, our Board of Directors approved a forward stock split in the form of a dividend with a record date of November 13, 2007 and effective on or about November 19, 2007, as a result of which each share of Common Stock then issued and outstanding converted into twelve shares of Common Stock.

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. Since its formation, KY USA has focused its business efforts on raising funds, acquiring working and revenue interests in property leases, putting together an experienced team of technical and business people and operations related to and including the drilling of its initial wells.

Our ability to emerge from the exploration stage with respect to any planned principal business activity is dependent upon our successful efforts to raise additional equity financing and generate significant revenue through our operations. There is no guarantee that our efforts will be sufficient to accomplish any of the above objectives.

Our principal offices are located at 321 Somerset Road, London, Kentucky 40741, and our telephone number is (606) 878-5987. Our website address is www.kusaenergy.com.

Merger

On May 2, 2008, the Company, KY Acquisition Corp., a Kentucky corporation and 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, with KY USA being the surviving corporation and becoming a wholly-owned subsidiary of the Company (the “Merger”).

At the closing of the Merger, each share of KY USA’s common stock issued and outstanding immediately prior to the closing of the Merger was converted into 9,000 shares of our Common Stock. An aggregate of 18,000,000 shares of our Common Stock were issued to the holders of KY USA’s common stock. In order to secure the indemnification obligations of the KY USA stockholders pursuant to the Merger Agreement, 5% of the shares of the Company’s Common Stock that KY USA’s pre-Merger stockholders received in exchange for their shares of KY USA are being held in escrow until May 2, 2010 (the “Indemnification Escrow”).

The Company, KY USA and Acquisition Sub each provided pre-closing covenants and closing conditions and customary representations and warranties in the Merger Agreement. Customary indemnification provisions in the Merger Agreement protect the parties from breaches of these representations and warranties. The Merger Agreement provided for a post-closing adjustment in an aggregate amount of up to 2,000,000 additional shares of Common Stock issuable pro rata to KY USA’s pre-Merger stockholders for any breach of the Merger Agreement by the Company that is discovered during the two-year period following the closing of the Merger. In order to secure the indemnification obligations of the KY USA stockholders pursuant to the Merger Agreement, 5% of the shares of Common Stock that KY USA’s pre-Merger stockholders received in the Merger in exchange for their shares of KY USA are being held in escrow for two years. Additionally, in connection with the Merger and pursuant to the Merger Agreement, 5,000,000 shares of the Company’s Common Stock are being held in escrow for issuance to the Company’s investor relations consultants as payment for their services to be rendered to the Company.

Split-Off

Immediately following the closing of the Merger, under the terms of a Split-Off Agreement, the Company transferred all of its pre-Merger operating assets and liabilities to its wholly-owned subsidiary, Las Rocas Leaseco Corp., a Delaware corporation (“Leaseco”). Thereafter, pursuant to the Split-Off Agreement, the Company transferred all of the outstanding capital stock of Leaseco to Christopher Greenwood, a former officer and director of the Company, in exchange for cancellation of 24,000,000 shares of Common Stock held by Mr. Greenwood as well as certain covenants and indemnifications (the “Split-Off”).

Our Natural Shale Gas Business

We are a exploration stage, independent energy company organized to exploit and develop the plentiful gas resources of the Illinois Basin’s New Albany Shale. We have acquired a 75% net revenue interest in a leasehold of approximately 3,000 acres in the Illinois Basin in western Kentucky, which permits us to extract and sell natural gas from the New Albany Shale formation in that location. As part of an agreement on a $10,000,000 credit facility to develop this leasehold (discussed below), we have pledged a 6% overriding royalty interest to NSES 12, LLC. As a result, our working interest in this leasehold has been reduced to a net 69% working interest.

We expect to create stockholder value and generate long-term reserve and production growth through drilling activities on our western Kentucky leasehold and through further acquisitions of additional properties. We believe that our management’s experience and expertise will enable us to successfully exploit our current resources and to identify, evaluate, and develop future natural gas projects.

Our Properties

On October 4, 2007, KY USA entered into three Farm-Out Assignment Agreements, subsequently supplemented and corrected (the “K&D Assignments”), with K & D Energy, pursuant to which for a cost of approximately $1.7 million, KY USA secured a 100% working interest being a 75% net revenue interest in ten separate mineral leases in Christian, Muhlenberg and Todd Counties in the Illinois Basin in Western Kentucky covering approximately 3,000 acres1 (the “K&D Leasehold” or the “K&D Properties”) targeting the New Albany Shale. Pursuant to the K&D Assignments, KY USA is entitled to all working rights to, and a 75% net revenue interest in, the hydrocarbons in the New Albany Shale (Devonian), being a shale formation approximately 275 feet thick directly beneath the Lower Mississippian formation, the depth below the surface being from approximately 1,850 feet to 3,000 feet, on the K&D Leasehold. These K&D Assignments give us the right to drill wells on the K&D Properties and extract from these wells and sell the natural gas found in or below the New Albany Shale formation running through the K&D Properties. Pursuant to the K&D Assignments, KY USA is required to drill 12 wells per year within the K&D Properties to maintain its rights under the K&D Assignments. We expect to meet this drilling requirement. We have identified approximately 40-50 drilling locations on the K&D Properties and we expect that the wells we drill will measure from 2,300 to 3,000 feet deep.

A map showing the location of our initial wells that we have drilled on the K&D Leasehold and that we propose to drill is attached hereto as Exhibit 99.1 and is incorporated into this report by reference.

1. The Company had initially reported that its K&D Leasehold covered approximately 2,092 acres. We are now correcting that number to an estimated 3,000 acres, to reflect the inclusion of the approximate acreage under one of our farm-out assignments where title to a particular lease included in the assignment had been in question and which had not previously been included in the gross acreage total. All title issues with respect to this property have been resolved in our favor.

Thomasson Farm-Out and 7921 Energy Joint Venture

On August 24, 2009, KY USA entered into a farm-out agreement (the TPE Farm-Out Agreement”) with Thomasson Petroleum Enterprises, Inc. (“TPE”) to acquire from TPE certain drilling rights on farm-out acreage in Todd, Muhlenberg and Christian counties in western Kentucky adjacent to our existing K&D Leasehold. Under the terms of the TPE Farm-Out Agreement, KY USA acquired the right to drill up to 40 wells on the subject leases 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 New Albany shale on the TPE acreage and an 18.75% net revenue interest in any oil “twin wells” drilled above the top of the Albany shale.

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 TPE acreage. The wells to be drilled under the JV agreement will utilize our field gathering system that has been 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 drilling and developing up to 40 wells on the newly acquired TPE farm-out 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. 7921 will also retain the option to participate with KY USA in the drilling of the up to 30 additional wells on the TPE acreage.

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 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. 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 be drilling, the Hardison #1 well. We have moved a drilling rig onto this location and have begun to “rig-up” for drilling.

If the first 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 agreement. Under the assignment, we shall be entitled to a seventy-five percent (75%) net revenue working interest in each producing well that we develop on this 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.

Proved Reserves

Our net recoverable “proved developed producing reserves2” as of October 31, 2009, as determined by Robinson Engineering & Oil Company, Inc., an independent petroleum engineering firm (“Robinson Engineering”), in a report to us dated January 26, 2010, are estimated at 1.825 billion cubic feet of gas (“Bcf”), while “proved undeveloped primary reserves3” are estimated at 23.725 Bcf, for a total proved developed and un-developed reserves of 25.550 Bcf. These January 26, 2010 estimates are the same as reported to us by Robinson Engineering on February 26, 2009, but reflect a decrease of 1.107 Bcf from estimates as of October 31, 2007. As calculated by Robinson Engineering in its reserves report, the estimated net present value of our total proved reserves as of October 31, 2009 (reflecting our 69%4 net revenue interest) over a 20 year production period totaled $20,153,808, discounted at 10% per year. These calculations assume, among other things, a price of $5.04 per thousand cubic feet of gas (“Mcf”), the NYMEX (New York Mercantile Exchange) market price as of October 31, 2009, a Kentucky State severance tax of 5% and 70 producing wells on the K&D Leasehold. These standardized estimates are not intended to represent the current market value of our estimated natural gas reserves. For additional information regarding our reserves, please see Note 13 to our consolidated financial statements as of and for the fiscal year ended October 31, 2009.

2. 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.

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.

4. Net of the 6% override we are required to pay the Lender under the Credit Agreement (defined below).

The K&D Leasehold is directly adjacent to third party producing wells - our western Kentucky acreage is located in the middle of a number of ongoing aggressive drilling projects managed by several other energy companies. We have purchased the rights to drill for and extract only the natural gas out of the New Albany shale formation on the K&D Properties. Although there are operating oil wells on the K&D Properties, we do not have any rights to the oil under the K&D Leasehold and we anticipate that we will not pursue any oil rights, since we will be concentrating our efforts on the natural gas found in the New Albany shale formation.

Well Development Status

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

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 chart below shows the progress we have made at our initial wells, as of January 19, 2010.

Well Name

Drilling Order

Spudded

Logged

Casing

Cement

Perf’ed

Frac’ed

4Pt

Test

CR5

Francis Grace # 1

2626’

Hunter Wells # 3

2509’

Hunter Wells # 2

2340’

B. Johnston # 1

2387’

Slinker # 1B

2340’

Walker #1

2430’

Hunter Wells #1

2431’

Francis Grace #2

2395’

J Johnston #27

3011’

10.

Francis Grace #3

2578’

11.

Golden Eagle #1

2760’

12.

Hunter Wells #4

2721’

13.

J Johnston #4

2500’

14.

B. Johnston #2

2640’

15.

Slinker #2

2618’

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

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

7.	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.

Well Name

Drilling Order

Spudded

Logged

Casing

Cement

Perf’ed

Frac’ed

4Pt

Test

CR5

16.

Jackson #1

2664’

17.

Swinney #1

3460’

We have recently 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 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
Hardison #1		X

The Sale of our Natural Gas

On October 19, 20098, 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 MMBtus (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.

We will sell our gas to Seminole following treatment 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 (14) of our wells are now connected to this system.

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

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, 20099.

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.

The sale of our gas to Seminole since our tie-in to the Seminole gathering and processing facility has been minimal, however, and the flow of our gas into the Seminole facility has been intermittent, due to a bottleneck at the Seminole facility created as a result of the increased gas volume flowing from our wells into the facility. Because of the potential increased sales volume expected from our wells, Seminole has been adding new equipment to its facilities to increase efficiencies and improve Seminole’s ability to accept our natural gas into its facility. Once the Seminole facility upgrade is complete, we will work 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 over the several weeks following completion of the facility upgrade.

Change in Fiscal Year

Prior to the Merger our fiscal year end was February 28 and the fiscal year end of KY USA (the accounting acquirer) was October 31. Following published Securities and Exchange Commission (“SEC”) accounting and financial reporting interpretations and guidance and in connection with the Merger, we changed our fiscal year end to October 31 to match that of KY USA.

Employees

We currently have two (2) full-time employees, including Steven D. Eversole, our President and Chief Executive Officer, and C.G. Collins, our Vice President of Exploration and Development. Our Interim Chief Financial Officer, Charles Stivers, is serving in this capacity on an independent contractor basis.

The Natural Shale Gas Business

Shale gas is essentially natural gas contained within a sequence of predominantly fine grained rocks, dominated by shale. Shale gas plays are considered “area plays”, as natural gas is found over large contiguous areas. Most shales have low matrix permeabilities, and usually require natural fracture systems to sustain commercial production rates.

The name “New Albany Shale” refers to brownish-black shale exposed along the Ohio River at New Albany in Floyd County, Indiana, and is present in the subsurface throughout much of the Illinois Basin. The Illinois Basin covers approximately 60,000 square miles in parts of Illinois, southwestern Indiana and western Kentucky. The New New Albany Shale has produced natural gas since 1858, mostly from wells located in southwestern Indiana and western Kentucky. As with other organic shale reservoirs, the Albany Shale gas is stored both as free gas in fractures and as absorbed gas on kerogen and clay surfaces within the shale matrix. Wells typically begin producing high volumes of water and low volumes of gas when a new area is first brought into production. As more and more wells are drilled in an area, the formation becomes dewatered and the gas continues to desorb from the shale. An initially high level of water is a positive indicator of natural fracturing in the New Albany Shale.

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

The Company has acquired the Leasehold, and is developing that property as discussed above, and intends to acquire additional producing oil and gas property rights where the Company believes significant additional value can be created. Management is primarily interested in properties where some combination of the following factors exists:

(1)

there are opportunities for long production life with stable production levels;

(2)

geological formations have multiple producing horizons allowing for gas extraction over overlapping time lines;

(3)

there is substantial exploration potential; and

(4)

there is relatively low capital investment and production cost.

Governmental Regulation

Our operations are or will be subject to various types of regulation at the federal, state and local levels. Such regulation includes requiring local permits for the drilling of wells; maintaining bonding requirements in order to drill or operate wells; implementing spill prevention plans; submitting notification and receiving permits relating to the presence, use and release of certain materials incidental to oil and gas operations; and regulating the location of wells, the method of drilling and casing wells, the use, transportation, storage and disposal of fluids and materials used in connection with drilling and production activities, surface usage and the restoration of properties upon which wells have been drilled, the plugging and abandoning of wells and the transporting of production. Our operations are or will also be subject to various conservation matters, including the regulation of the size of drilling and spacing units or proration units, the number of wells which may be drilled in a unit and the unitization or pooling of oil and gas properties. In this regard, some states allow the forced pooling or integration of tracts to facilitate exploration while other states rely on voluntary pooling of lands and leases, which may make it more difficult to develop oil and gas properties. In addition, state conservation laws establish maximum rates of production from oil and gas wells, generally limit the venting or flaring of gas, and impose certain requirements regarding the ratable purchase of production. The effect of these regulations is to limit the amounts of oil and gas we may be able to produce from the wells and to limit the number of wells or the locations at which we may be able to drill.

Our business is affected by numerous laws and regulations, including energy, environmental, conservation, tax and other laws and regulations relating to the oil and gas industry. We plan to develop internal procedures and policies to ensure that operations are conducted in full and substantial environmental regulatory compliance.

Our failure to comply with any laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of injunctive relief or both. Moreover, changes in any of these laws and regulations could have a material adverse effect on our business. In view of the many uncertainties with respect to current and future laws and regulations, including their applicability to us, we cannot predict the overall effect of such laws and regulations on future operations.

We believe that our operations comply in all material respects with applicable laws and regulations and that the existence and enforcement of such laws and regulations have an effect no more restrictive on our operations than on other similar companies in the energy industry. The Company does not anticipate any material capital expenditures to comply with federal and state environmental requirements.

Environmental Regulation

Our operations on properties in which we have an interest are subject to extensive federal, state and local environmental laws that regulate the discharge or disposal of materials or substances into the environment and otherwise are intended to protect the environment. Numerous governmental agencies issue rules and regulations to implement and enforce such laws, which are often difficult and costly to comply with and which carry substantial administrative, civil and criminal penalties and in some cases injunctive relief for failure to comply.

Some laws, rules and regulations relating to the protection of the environment may, in certain circumstances, impose “strict liability” for environmental contamination. These laws render a person or company liable for environmental and natural resource damages, cleanup costs and, in the case of oil spills in certain states, consequential damages without regard to negligence or fault. Other laws, rules and regulations may require the rate of oil and gas production to be below the economically optimal rate or may even prohibit exploration or production activities in environmentally sensitive areas. In addition, state laws often require some form of remedial action, such as closure of inactive pits and plugging of abandoned wells, to prevent pollution from former or suspended operations.

Legislation has been proposed in the past and continues to be evaluated in Congress from time to time that would reclassify certain oil and gas exploration and production wastes as “hazardous wastes.” This reclassification would make these wastes subject to much more stringent storage, treatment, disposal and clean-up requirements, which could have a significant adverse impact on our operating costs. Initiatives to further regulate the disposal of oil and gas wastes are also proposed in certain states from time to time and may include initiatives at the county, municipal and local government levels. These various initiatives could have a similar adverse impact on our operating costs.

The regulatory burden of environmental laws and regulations increases the cost and risk of doing business and consequently affects profitability. The federal Comprehensive Environmental Response, Compensation and Liability Act, or CERCLA, also known as the “Superfund” law, imposes liability, without regard to fault, on certain classes of persons with respect to the release of a “hazardous substance” into the environment. These persons include the current or prior owner or operator of the disposal site or sites where the release occurred and companies that transported, disposed or arranged for the transport or disposal of the hazardous substances found at the site. Persons who are or were responsible for releases of hazardous substances under CERCLA may be subject to joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment and for damages to natural resources, and it is not uncommon for the federal or state government to pursue such claims.

It is also not uncommon for neighboring landowners and other third parties to file claims for personal injury or property or natural resource damages allegedly caused by the hazardous substances released into the environment. Under CERCLA, certain oil and gas materials and products are, by definition, excluded from the term “hazardous substances.” At least two federal courts have held that certain wastes associated with the production of crude oil may be classified as hazardous substances under CERCLA. Similarly, under the federal Resource, Conservation and Recovery Act, or RCRA, which governs the generation, treatment, storage and disposal of “solid wastes” and “hazardous wastes,” certain oil and gas materials and wastes are exempt from the definition of “hazardous wastes.” This exemption continues to be subject to judicial interpretation and increasingly stringent state interpretation. During the normal course of our operations on properties in which we have an interest, exempt and non-exempt wastes, including hazardous wastes, that are subject to RCRA and comparable state statutes and implementing regulations are generated or have been generated in the past. The federal Environmental Protection Agency and various state agencies continue to promulgate regulations that limit the disposal and permitting options for certain hazardous and non-hazardous wastes.

We have established guidelines and management systems to ensure compliance with environmental laws, rules and regulations. The existence of these controls cannot, however, guarantee total compliance with environmental laws, rules and regulations. We believe that with respect to the K&D Properties, we are in substantial compliance with applicable environmental laws, rules and regulations. We do not currently maintain any insurance against the risks described above, and there is no assurance that we will be able to obtain insurance that is adequate to cover all such costs or that insurance will be available at premium levels that justify purchase. The occurrence of a significant event not fully insured or indemnified against could have a material adverse effect on our financial condition and operations. Compliance with environmental requirements, including financial assurance requirements and the costs associated with the cleanup of any spill, could have a material adverse effect on our capital expenditures, earnings or competitive position. We do believe, however, that the operators are in substantial compliance with current applicable environmental laws and regulations. Nevertheless, changes in environmental laws have the potential to adversely affect our operations. At this time, we have no plans to make any material capital expenditures for environmental control facilities.

Competition

The oil and gas exploration and production industry is highly competitive. In the New Albany Shale area, we compete with several large and well known public and private companies such as Southwestern Energy Corporation, Chesapeake Energy Resources, CNX Gas Corporation and NGAS Resources Inc., which companies may have more financial and operational resources than we do. Western Kentucky is one of new emerging shale gas areas and is attracting a great deal of industry interest. Competition for equipment, personnel and services is expected to be similar to that in the Barnett Shale area of Texas.

Plan of Operation

Our strategy is to pursue selected opportunities that are characterized by reasonable entry costs, favorable economic terms, high reserve potential relative to capital expenditures and the availability of existing technical data that may be further developed using current technology.

We seek to achieve attractive returns on capital for the benefit of stockholders through investment in existing developmental plays, rather than through our own exploratory efforts. In this way we hope to maintain a strong balance sheet to enable us to be flexible from an operational and financial standpoint.

We expect to generate long-term reserve and production growth through drilling activities and further acquisitions. We believe that our management’s experience and expertise will enable us to identify, evaluate, and develop natural gas projects.

While we anticipate that the majority of our future capital expenditures will be applied to the drilling of wells, we intend to use our experience and regional expertise to add leasehold interests as well as direct property acquisitions to our inventory of properties for future drilling activities.

Disciplined Acquisition Strategy

We intend to acquire producing oil and gas properties where we believe significant additional value can be created. Management is primarily interested in developmental properties where some combination of these factors exist: (1) opportunities for long production life with stable production levels; (2) geological formations with multiple producing horizons; (3) substantial exploitation potential; and (4) relatively low capital investment for production costs. We are currently reviewing several thousand lease acres in western Kentucky with an expected potential similar to that of our K&D Properties. This property is geologically the same as the acreage where we are presently drilling, although we cannot assure you that hydrocarbons will be present in commercial volumes or in volumes similar to those estimated to be on our current K&D Properties.

Exploitation of K&D Properties

We intend to maximize the value of the K&D Properties, and any additional properties we acquire, through a combination of successful drilling, increasing recoverable reserves and reducing operating costs. We will employ the latest technologies where applicable. Newer completion techniques enable operators to produce oil and gas at faster rates and with lower operating costs.

Experienced and Dedicated Personnel

The Company is led by an experienced team of energy industry veterans with direct exploration and production experience in the region, having worked for companies that drilled and/or developed over 800 wells in Kentucky, Tennessee, Illinois, and Indiana.

We intend to maintain a highly competitive team of experienced and technically proficient employees and motivate them through a positive work environment, competitive salaries and stock ownership. We believe that employee ownership, which is encouraged through our 2007 Plan, is essential for attracting, retaining and motivating qualified personnel.

PART II

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion highlights the principal factors that have affected our financial condition and results of operations as well as our liquidity and capital resources for the periods described. This discussion contains forward-looking statements. Please see “Forward-Looking Statements” and “Risk Factors” for a discussion of the uncertainties, risks and assumptions associated with these forward-looking statements.

The following discussion and analysis of the Company’s financial condition and results of operations are based on the consolidation of KY USA’s financial statements, which KY USA has prepared in accordance with U.S. generally accepted accounting principles. You should read the discussion and analysis together with such financial statements and the related notes thereto.

Results of Operations

Fiscal year Ended October 31, 2009 compared to 2008

We are still in our exploration stage and have generated no revenues to date.

All productive and 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 year ended October 31, 2009, we incurred such total capitalized costs of $3,999,725, compared to $3,051,737 for the year ended October 31, 2008.

We incurred general and administrative expenses of $195,715 for the year ended October 31, 2009, compared to $46,527 for the year ended October 31, 2008. These expenses consisted of costs incurred in connection with the start-up and day to day operation of our business and costs relating to the Merger.

Amortization of loan fees for the year ended October 31, 2009 totaled $364,396, compared to $145,115 for the year ended October 31, 2008. These costs are related to the Note and the Loan (defined below).

We incurred legal and accounting expenses of $192,141 for the year ended October 31, 2009, compared to $676,217 for the year ended October 31, 2008. These expenses consisted of costs incurred in connection with our recent financing activities and SEC filing requirements. Also included in this number for the year ended October 31, 2009 is $894,930 in expenses reflecting the dollar value of shares of our Common Stock issued to consultants.

Our interest expense for the year ended October 31, 2009, was $159,544, compared to $7,094,735 for the year ended October 31, 2008. This cost is attributable to interest due and paid on the Note and on the Loan. During the year ended October 31, 2009, we recognized a net gain on a derivative liability relating to the Note in the amount of $558,206 compared to $4,596,769 for the year ended October 31, 2008, due to a partial settlement and revaluation of the derivative liability to market at October 31, 2009 and 2008, respectively.

Our net operating loss from inception through October 31, 2009 was $4,922,556.

Liquidity and Capital Resources

Our cash and cash equivalents balance as of October 31, 2009 was $59,105.

As a result of the Merger which closed on May 2, 2008 and our work program begun at that time, we expect significant expenditures during the next 12 months. Pursuant to the terms of the K&D Assignments, KY USA is required to drill 12 wells per year within the K&D Properties at an estimated cost of between $165,000 to $225,000 per well, for a maximum total of approximately $2.7 million for the year. Additionally, we are required to drill 10 wells in the first year under the TPE farm-out agreement. Since June 27, 2008, we have been using the proceeds of the Note Offering and Initial Loan to finance our drilling efforts on our initial wells. In addition to the $2,500,000 Initial Loan, we have received additional Installment Loans under the Credit Facility on February 12, 2009, August 14, 2009 and December 11, 2009 totaling in the aggregate an additional $4,300,000. We plan to use the balance of these funds to bring our presently drilled wells online and to begin our program to drill an additional 10 to 12 wells on our K&D Leasehold. With respect to the drilling requirements under the TPE farm-out agreement, we have entered into a JV agreement with 7921 under which 7921 will provide working capital to be used to drill the TPE leasehold wells. There can be no assurance, however, that we will receive any additional Installment Loans or that if we do receive them, they will be for the remaining maximum amount available under the Credit Facility, $3,150,000. Also, we cannot be sure that our JV with 7921 will proceed and that 7921 will provide the funds they have agreed to contribute. If we do not receive any subsequent Installment Loans under the Credit Facility or 7921 does not provide its promised funds, we will be required to enter the capital markets to raise working capital. If we are unable to obtain the financing necessary to support our current and planned operations or we do not drill the required K&D Leasehold or TPE leasehold wells, we will lose all or part of our rights to the K&D Leasehold and the TPE leasehold, respectively. The loss of the K&D Leasehold or the TPE would have a substantial material adverse impact on our business and we might not be able to continue as a going concern. We currently have no commitments for any additional capital.

In addition to our current drilling program on the K&D Leasehold, and contingent upon our ability to raise the required capital, we expect to engage in additional expenditures over the next 12 months for new seismic data acquisitions and/or land and drilling rights acquisitions and related drilling programs. Although we are not ready to move forward on any particular project, we would require additional financing in order to proceed with any such project. There can be no assurance, however, that financing for one or more of these projects will be available to us or, if it is available, that it will be available on terms acceptable to us and that it will be sufficient to fund our needs. If we are unable to obtain the financing necessary to support these expenditures, we may not be able to proceed with this aspect of our plan of operation.

Due to our brief history and historical operating losses, our operations have not been a source of liquidity. Although we expect to begin generating revenues from the sale of gas from our wells within the next six months, there can be no assurances that we will be successful in reaching this milestone in a timely fashion or that we will be able to generate sufficient liquidity from the sale of our natural gas to help fund our operations. If we cannot generate revenues from the sale of our gas, our business, results of operations, liquidity and financial condition may suffer materially.

Various factors outside of our control, including the price of natural gas, overall market and economic conditions, the downturn and volatility in the US equity markets and the trading price of our common stock may limit our ability to raise the capital needed to execute our plan of operations. We recognize that the US economy is currently experiencing a period of uncertainty and that the capital markets have been depressed from recent levels. If the price of natural gas continues to drop and the markets remain volatile, we realize that these or other factors could adversely affect our ability to raise additional capital. As a result of an inability to raise additional capital, our short-term or long-term liquidity and our ability to execute our plan of operations could be significantly impaired.

Note Offering

On May 29, 2008 we closed the Note Offering for aggregate gross proceeds to us of $2.5 million. We paid cash commissions of ten percent (10%) and ten percent (10%) warrant coverage to a registered broker-dealer and its designee in connection with the Note Offering. We have used the net proceeds of this financing to begin drilling our initial wells, to repay certain outstanding indebtedness and for general working capital purposes. On May 29, 2009, with the consent of the Note Investor, we amended the Note to extend the initial installment payment date of the Note to May 29, 2010.

Credit Facility

On June 27, 2008, KY USA entered into the Credit Agreement with the Lender pursuant to which KY USA has borrowed $6,850,000 to date.

The Credit Agreement requires that we comply with financial covenants relating to, among other things, collateral and current ratio coverage. As of October 31, 2008, we were 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. Although the Lender has informed us that it will not take any actions against us with respect to this breach, we may request from the Lender a waiver of this current ratio covenant. If we do request such a written waiver, we cannot assure you that we will be successful in obtaining it. Additionally, even if we obtain a written 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 concern.

Notes Issued by KY USA

On October 5, 2007, KY USA issued a promissory note to K&D with a principal amount of $1,000,000 (the “K & D Note”). The “K & D Note was due and payable on August 5, 2008 and did not bear interest until that date. After the Maturity Date, interest accrues at a rate of nine percent (9%) per annum on any outstanding principal. The “K & D Note was issued in partial payment for KY USA’s acquisition of its interest in the K&D Properties, which it acquired from K&D. The Company repaid $350,000 principal amount of the K & D Note out of the proceeds of the Note Offering.

On October 5, 2007, KY USA entered into a loan agreement (the “Loan Agreement”) with Somerset Recycling Service, Inc. (“Somerset”) pursuant to which Somerset loaned KY USA $800,000 evidenced by a promissory note (the “Somerset Promissory Note”). The Somerset Promissory Note was due and payable on June 15, 2008, and bore interest at 10% per annum, payable monthly. Upon closing of the Merger, Somerset received warrants to purchase 2,000,000 shares of Common Stock (the “Somerset Warrants”), such warrants having an exercise price of $1.00 and expiring five years after issuance. Somerset exercised the Somerset Warrants on a cashless basis and received 1,194,592 shares of the Common Stock. The Company repaid $100,000 of the principal amount of the Somerset Promissory Note out of the proceeds of the May 9th Promissory Note. (See below.) The Company repaid the remaining $700,000 principal amount of the Somerset Promissory Note out of the proceeds of the Note Offering.

On January 17, 2008, KY USA entered into a loan agreement with John Thomas Bridge and Opportunity Fund (“John Thomas”) pursuant to which John Thomas loaned KY USA $100,000 evidenced by a promissory note (the “John Thomas Promissory Note”). The John Thomas Promissory Note was due and payable on June 17, 2008, and bore interest at 10% per annum. Upon closing of the Merger, John Thomas received warrants to purchase 250,000 shares of Common Stock (the “John Thomas Warrants”), such warrants having an exercise price of $1.00 and expiring five years after issuance. The Company repaid the John Thomas Promissory Note out of the proceeds of the Note Offering.

On May 9, 2008, the Company issued a promissory note (the “May 9th Promissory Note”) with a principal amount of $100,000 to one lender. The May 9th Promissory Note was due and payable on June 15, 2008, and bore interest at 10% per annum. Upon closing of the Merger, this lender received warrants to purchase 200,000 shares of Kentucky USA Common Stock (the “May 9th Bridge Warrants”), such warrants having an initial exercise price of $1.00 per share and expiring five years after issuance. The Company repaid the May 9th Promissory Note out of the proceeds of the Note Offering.

Significant Accounting Policies

Our consolidated financial statements and accompanying notes have been prepared in accordance with United States generally accepted accounting principles applied on a consistent basis. The preparation of financial statements in conformity with U.S. generally accepted accounting principles requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting periods.

For a discussion of all of our significant accounting policies, see Note 3 to our Consolidated Financial Statements included in this Annual Report on Form 10-K.

Recent Accounting Pronouncements

On December 31, 2008, the SEC published the final rules and interpretations updating its oil and gas reporting requirements. Many of the revisions are updates to definitions in the existing oil and gas rules to make them consistent with the petroleum resource management system, which is a widely accepted standard for the management of petroleum resources that was developed by several industry organizations. Key revisions include 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, the ability to include nontraditional resources in reserves, the use of new technology for determining reserves, and 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. Early adoption is not permitted. The Company is currently assessing the impact that the adoption will have on the Company’s disclosures, operating results, financial position and cash flows.

In June 2009, the FASB issued guidance now codified as ASC 105, Generally Accepted Accounting Principles as the single 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, aside from those issued by the SEC.

ASC 105 does not change current U.S. GAAP, but is intended to simplify user access to all authoritative U.S. GAAP by providing all authoritative literature related to a particular topic in one place. The adoption of ASC 105 did not have a material impact on our company’s consolidated financial statements, but did eliminate all references to pre-codification standards.

In May 2009, FASB issued ASC 855, Subsequent Events which establishes general standards of for the evaluation, recognition and disclosure of events and transactions that occur after the balance sheet date. Although there is new terminology, the standard is based on the same principles as those that currently exist in the auditing standards. The standard, which includes a new required disclosure of the date through which an entity has evaluated subsequent events, is effective for interim or annual periods ending after June 15, 2009. The adoption of ASC 855 did not have a material effect on our company’s consolidated financial statements. The Company has a evaluated subsequent events through the date of the issuance of the financials. An additional borrowing of $1.2M on the NSES credit facility occurred after the balance sheet date and before the date of issuance.

Our company has implemented all new accounting pronouncements that are in effect and that may impact our financial statements and we do not believe that there are any other new accounting pronouncements that have been issued that might have a material impact on our financial position or results of operations.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTAL DATA

Our audited financial statements are included beginning immediately following the signature page to this report. See Item 15 for a list

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, as amended, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	KENTUCKY USA ENERGY, INC.

Dated: May 1, 2010	By:	/s/ Steven D. Eversole
		Steven D. Eversole, President and
		Chief Executive Officer

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and

Stockholders of Kentucky USA Energy, Inc.

We have audited the accompanying balance sheets of Kentucky USA Energy, Inc. (an exploration stage company) as of October 31, 2009 and 2008, and the related statements of operations, stockholders’ equity, and cash flows for each of the years in the two year period ended October 31 2009 and for the period from inception (October 5, 2007) to October 31, 2009. The management of Kentucky USA Energy, Inc. is responsible for these financial statements. Our responsibility is to express an opinion on these financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. The company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of Kentucky USA Energy, Inc. as of October 31, 2009 and 2008, and the results of its operations and its cash flows for each of the years in the two-year period ended October 31, 2009 and for the period from inception (October 5, 2007) to October 31, 2009 in conformity with accounting principles generally accepted in the United States of America.

The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2 to the financial statements, the Company has suffered recurring losses from operations and has breached a loan covenant, whereby funds may be subject to accelerated repayment. Additionally, the Company is behind schedule on progress specified in its K&D farm-out agreement, which could trigger forfeiture of its rights under the farm-out agreement. These circumstances raise substantial doubt about the Company’s ability to continue as a going concern. Management's plans in regard to these matters are also described in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Rodefer Moss & Co, PLLC

Knoxville, Tennessee

February 16, 2010

F-1

KENTUCKY USA ENERGY, INC.

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

Consolidated Balance Sheets

	October 31, 2009			October 31, 2008
ASSETS
Current Assets
Cash and cash equivalents	$	59,105		$	899,037
Prepaid expenses		37,006			15,613

Total current assets		96,111			914,650

Other Assets
Loan fees, net of accumulated amortization of $509,511 and $145,115		640,694			1,005,090
Investment in natural gas properties, using full cost method		7,708,811			3,796,351

Total other assets		8,349,505			4,801,441

Other property and equipment, net of accumulated depreciation
of $42,258 and $7,830		450,650			306,366

Total assets	$	8,896,266		$	6,022,457

LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
Current Liabilities
Accounts payable	$	343,890		$	188,225
Accrued interest		522,303			81,928
Accrued liabilities		7,763			-
Stock liability		149,125			188,600
Derivative liability		1,015,971			1,723,453
Notes payable, due within one year		6,300,000			3,150,000
Capital lease obligations, due within one year		94,847			83,268

Total current liabilities		8,433,899			5,415,474

Long-term Debt
Convertible debt, net of discounts of $1,527,780 and $2,152,778		972,220			347,222
Capital lease obligations, less amounts due within one year		110,083			202,169

Total long-term debt		1,082,303			549,391

Total liabilities		9,516,202			5,964,865

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 36,194,592 shares issued and outstanding)		3,692			3,619
Additional paid-in capital		4,298,928			3,427,498
Deficit accumulated during exploration stage		(4,922,556	)		(3,373,525	)

Total stockholders' equity (deficit)		(619,936	)		57,592

Total liabilities and stockholders' equity	$	8,896,266		$	6,022,457

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

F-2

KENTUCKY USA ENERGY, INC.

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

Consolidated Statements of Operations

							From Inception,
	Year Ended			Year Ended			October 5, 2007, through
	October 31, 2009			October 31, 2008			October 31, 2009

General and Administrative Expenses
Amortization of loan fees	$	364,396		$	145,115		$	509,511
General and administrative		195,715			46,527			242,242
Compensation expense (including $895,728 of share-based compensation)		1,195,441			-			1,195,441
Legal and accounting		192,141			676,217			870,358

Loss from operations		(1,947,693	)		(867,859	)		(2,817,552	)

Other Income (expense)
Changes in fair value of derivative liability		558,206			4,596,769			5,154,975
Interest expense		(159,544	)		(7,094,735	)		(7,259,979	)

Loss before income taxes		(1,549,031	)		(3,365,825	)		(4,922,556	)

Income taxes		-			-			-

Net loss	$	(1,549,031	)	$	(3,365,825	)	$	(4,922,556	)

Net income per share
Basic and diluted:
Operations	$	(0.04	)	$	(0.12	)	$	(0.13	)
Total	$	(0.04	)	$	(0.12	)	$	(0.13	)

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

F-3

KENTUCKY USA ENERGY, INC.

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

Consolidated Statement of Changes in Stockholders’ deficit

								Deficit			Total
	Common				Additional			Accumulated			Stockholders’
	Stock		Common		Paid -in			During Exploration			Equity
	Shares		Stock		Capital			Stage			(Deficit)

Balance at October 5, 2007 (inception)		-	$	-	$	-		$	-		$	-

18,000,000 shares of stock issued for services on October 5, 2007 at $0.0001 per share		18,000,000		1,800		200			-			2,000
Net loss for the period		-		-		-			(7,700	)		(7,700	)
Balance at October 31, 2007		18,000,000		1,800		200			(7,700	)		(5,700	)

May 2008 issuance of 12,000,000 shares for shell acquisition		12,000,000		1,200		(1,000	)		-			200
May 2008 application of services provided in connection with recapitalization as a cost of the transaction		-		-		(8,500,000	)		-			(8,500,000	)
May 2008 issuance of 5,000,000 shares in connection with services for recapitalization		5,000,000		500		8,499,500			-			8,500,000
Issuance of stock in partial settlement of derivative liability - May 2008		1,194,592		119		3,428,798			-			3,428,917
Net loss for the year		-		-		-			(3,365,825	)		(3,365,825	)
Balance at October 31, 2008		36,194,592		3,619		3,427,498			(3,373,525	)		57,592

December 2008 issuance of 412,500 shares in connection with services provided		412,500		41		562,312			-			562,353
June 2009 issuance of 320,000 shares in connection with services provided		320,000		32		309,118			-			309,150

Net loss for the year		-		-		-			(1,549,031	)		(1,549,031	)
Balance at October 31, 2009		36,927,092	$	3,692	$	4,298,928		$	(4,922,556	)	$	(619,936	)

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

F-4

KENTUCKY USA ENERGY, INC.

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

Consolidated Statements of Cash Flows

							From Inception
	Year Ended			Year Ended			October 5, 2007 through
	October 31, 2009			October 31, 2008			October 31, 2009

Net loss	$	(1,549,031	)	$	(3,365,825	)	$	(4,922,556	)
Adjustments to reconcile net loss to net cash
flows from operating activities
Gains on market valuation of derivative liabilities		(558,206	)		(4,596,769	)		(5,154,975	)
Derivative valuation adjustments charged to expense		421,883			6,851,947			7,273,830
Amortization of loan fees		364,396			145,115			509,511
Depreciation		34,428			7,830			42,258
Common stock issued for services		871,503			-			873,503

(Increase) in assets and increase in liabilities
Prepaid expenses		(21,391	)		34,425			13,034
Accounts payable and accrued liabilities		163,428			188,225			351,653
Stock liability		(39,475	)		188,600			149,125
Accrued interest		440,375			76,229			522,304
Total adjustments to reconcile net loss to net cash from operating activities		1,676,941			2,895,602			4,580,243

Net cash flows from operating activities		127,910			(470,223	)		(342,313	)

Cash flows from investing activities
Purchase of other property and equipment		(178,712	)		(314,195	)		(492,907	)
Retainers paid to legal counsel		-			-			(50,040	)
Investment in oil & gas properties		(3,858,622	)		(1,332,009	)		(6,910,359	)

Total cash flows from investing activities		(4,037,334	)		(1,646,204	)		(7,453,306	)

Cash flows from financing activities
Proceeds from borrowings		3,150,000			5,100,000			10,050,000
Proceeds from borrowings under capital leases		-			307,394			307,394
Loan fees incurred from borrowings		-			(1,150,205	)		(1,150,205	)
Repayments of long-term debt		-			(1,250,000	)		(1,250,000	)
Payments on capital lease obligations		(80,508	)		(21,957	)		(102,465	)

Total cash flows from financing activities		3,069,492			2,985,232			7,854,724

Net change in cash		(839,932	)		868,805			59,105

Cash and cash equivalents, beginning of period		899,037			30,232			-

Cash and cash equivalents, end of period	$	59,105		$	899,037		$	59,105

Supplemental Disclosures of Cash Flow information
Cash paid for interest	$	369,167		$	181,812		$	550,979

For the year ended October 31, 2008, the Company entered in the following non-cash transactions:

The Company incurred noncash financing costs of $6,300,037.

The Company entered into capital lease obligations of $307,394 in order to obtain equipment for drilling.

Common stock was issued in the amount of $3,429,117 in settlement of warrants booked as derivative liabilities.

For the year ended October 31, 2009, the Company entered in the following non-cash transaction:

Common stock was issued in the amount of $871,503 for services provided to the Company.

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

F-5

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Note 1 - Basis of Presentation

The accompanying financial statements of Kentucky USA Energy, Inc. (the “Company”) have been prepared in conformity with accounting principles generally accepted in the United States of America. The company is still in the exploration stage, has recognized no revenue to date, and therefore has recorded no income tax expense.

These financial statements include the accounts of Kentucky USA Energy, Inc. and the accounts of its subsidiary, KY USA Energy, Inc. All inter-company balances have been eliminated in consolidation.

The Company is an exploration-stage company and historically has had almost no revenues. To date the Company's activities have generally been restricted to fundraising, drilling and exploring for natural gas.

The Company’s working capital ratio is less than one-to-one, which is a breach of our loan covenants in effect with regard to loans outstanding from our principal lender. Because of the breach of our loan covenant, the $5.65 million listed as due on our balance sheet at October 31, 2009, (Note 9) may be called by our lender. Should this happen, we would have to seek additional financing. There is no guarantee that additional financing would be available. If the loan is called and we are unable to find additional financing, we believe we have ample funding to last through October 31, 2010.

We continue to maintain a good relationship with this lender and believe that there is no intention by the lender to call our loan.

As a result of the covenant violation our loans with this lender are classified as currently due on our balance sheet at October 31, 2009.

Certain amounts in prior periods have been reclassified to conform to the report classifications of the year ended October 31, 2009 with no effect on previously reported net income or stockholders’ equity.

Note 2 – Going Concern

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 October 31, 2009 the Company’s liabilities exceed its assets. The Company is currently in default on the senior credit facility with NSES, and the NSES loan may be called. Additionally, the Company is behind schedule on drilling as specified in the K & D farm-out, currently does not have the funds to complete these drillings over the expected life of the K & D Assignments and will require additional funds to do so. In the event that 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 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.

F-6

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

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 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 in January, 2010. Management has maintained good relations with the principals and does not believe the Company’s failure to adhere to the specified schedule will lead to a material loss to the Company.

Note 3 – Significant Accounting Policies

Cash and Cash Equivalents

The Company considers all highly liquid investments with a maturity of three months or less when purchased to be cash equivalents. Financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of cash. The Company’s cash deposits are in a highly rated financial institution in Kentucky and may at times exceed federally insured amounts.

Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect the amounts reported on the financial statements and accompanying notes. Actual results may differ from those estimates. Gas reserve estimates are developed from information provided by the Company’s management to Glenn Robinson, Robinson Engineering of Evansville, Indiana at October 31, 2009 and October 31, 2008.

Natural Gas Properties

The Company follows the full cost method of accounting for gas property acquisition, exploration and development activities. Under this method, all productive and non-productive costs incurred in connection with the acquisitions of, exploration for, and development of gas reserves for each cost center is capitalized. Capitalized costs include lease acquisitions, geological and geophysical work, and the costs of drilling, completing and equipping gas wells. Costs, however, associated with production and general corporate activities are expensed in the period incurred. Interest costs related to proved properties and properties under development are also capitalized to gas properties. Gains or losses are recognized only upon sales or dispositions of significant amounts of gas reserves representing an entire cost center. Proceeds from all other sales or dispositions are treated as reductions to capitalized costs. The capitalized gas property, less accumulated depreciation, depletion and amortization and related deferred income taxes, if any, is 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 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 that are excluded from the costs being amortized.

F-7

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Issuance of Stock for Non-Cash Consideration

All issuances of the Company’s stock for non-cash consideration have been assigned a per share amount equaling either the market value of the shares issued or the value of consideration received, whichever is more readily determinable. The majority of the non-cash consideration received pertains to services rendered by consultants and others and has been valued at the market value of the shares on the dates issued.

Earnings per Share

In accordance with Statement of Financial Accounting Standards (SFAS) No. 128, “Earnings per Share” (“SFAS 128”), which was primarily codified into Topic 260, basic income per share is based on 36,927,092 and 36,194,592 weighted average shares outstanding for the years ended October 31, 2009 and October 31, 2008. Because the Company recorded a loss at October 31, 2009 and 2008, all potentially dilutive securities are anti-dilutive.

Income Taxes

Provisions for income taxes are based on taxes payable or refundable for the current year (after exclusion of non-taxable income) and deferred taxes on temporary differences between the amount of taxable and pretax income and between the tax bases of assets and liabilities and their reported amounts in the financial statements. Deferred tax assets and liabilities are reflected in the financial statements at income tax rates applicable to the period in which the deferred tax assets or liabilities are expected to be realized or settled as prescribed in ASC 740, Income Taxes. As changes in tax laws or rates are enacted, deferred tax assets and liabilities are adjusted through the provision for income taxes.

All of the Company’s tax years since inception are open to IRS examination.

F-8

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Note 4 – Other Property and Equipment

Other property and equipment consisted of the following:

	Depreciable Life	October 31, 2009			October 31, 2008

Machinery and Equipment	10-20 yrs	$	492,908		$	314,196
Total			492,908			314,196
Less accumulated depreciation			(42,258	)		(7,830	)
Other property and Equipment - net		$	450,650		$	306,366

The Company uses the straight-line method of depreciation ranging from ten to twenty years, depending on the estimated asset life.

Note 5 – Notes Payable and Convertible Debt

The Company had the following debt obligations:

	October 31, 2009		October 31, 2008
Non-interest bearing note payable to K & D Energy, secured by a Second mortgage on oil and gas leases, and repayable on or before August 5, 2008. This note is past due as at October 31, 2008 and as a result is currently bearing interest at 9%.	$	650,000	$	650,000

Note payable to Tillerman Securities. Secured by oil and gas properties, bearing interest at 8%, interest due quarterly. See Note 9.		2,500,000		2,500,000

NSES 12, LLC-New Stream Capital 12% note with interest payable monthly starting October 1, 2008, 85% of adjusted cash flow starting October 1, 2008 Interest & Principal paid full in 3 years		5,650,000		2,500,000

	$	8,800,000	$	5,650,000

F-9

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Maturities under note obligations at October 31, 2009 and 2008 were:

	2009		2008
Year ending October 31:
2010	$	6,300,000	$	3,150,000
2011		2,500,000		2,500,000

Total maturities of long-term debt		8,800,000		5,650,000
Less current maturities		6,300,000		3,150,000
Long-term notes payable	$	2,500,000	$	2,500,000

The convertible Tillerman note is included on the balance sheets, net of discount, as follows:

	2009			2008

Face amount of note	$	2,500,000		$	2,500,000
Discount		(1,527,780	)		(2,152,778	)
	$	972,220		$	347,222

The balance owed to NSES represents drawdowns on a potential $10 million credit facility with which the Company plans to execute its drilling program. Management believes the liquidity provided by this arrangement will be sufficient for its cash needs in its fiscal year ending October 31, 2010. For a further discussion of this arrangement, see Note 9.

The Company’s investment in natural gas properties reflects capitalized interest of $1,997,416 and $744,614 related to its debt obligations for October 31, 2009 and 2008, respectively.

Note 6 – Capital Lease

On August 4, 2008, KY entered into a capital lease with The Magdovitz Family Trust. The lease is for drilling equipment with a total lease price of $307,394. The terms of the lease require the Company to make forty-two monthly installments, beginning on August 4, 2008. At the conclusion of the lease, the Company will have available a bargain purchase option for the equipment which at October 31, 2009 has a carrying value of $204,910.

F-10

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Year ending October 31:
2010	$	94,827
2011		94,827
2012		15,256

Total gross minimum lease payments		204,910
Less current installments of obligations		94,827

Long-term capital lease due	$	110,083

Note 7 – Provision for Income Taxes

The Company provides deferred income tax assets and liabilities using the liability method for temporary differences between book and taxable income.

The provisions for income taxes for the years ended October 31, 2009 and 2008 are comprised as follows:

	2009			2008

Currently payable	$	-		$	-
Deferred federal tax benefit (expense)		337,000			147,000
Deferred state tax benefit (expense)		42,000			29,000
Valuation adjustment		(379,000	)		(176,000	)

	$	-		$	-

Income tax benefit (expense) attributable to income (loss) before income taxes differed from the amounts computed by applying the United States of America federal income tax rate of 34% to income (loss) before income taxes as a result of the following:

F-11

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

	October 31, 2009			October 31, 2008
Reconciliation between statutory and effective tax rates

Expected benefit at federal statutory rates	$	527,000		$	1,144,000

Effect of interest expense deductible for book purposes but not deductible for income tax purposes					(2,324,000	)

Effect of derivative gains included in book income but not included in taxable income		190,000			1,563,000
Temporary difference – capitalization of interest					(67,000	)
State income taxes		42,000			29,000
Effect of expected lower applicable rates		(380,000	)		(169,000	)

		379,000			176,000
Valuation allowance		(379,000	)		(176,000	)

Income tax provision	$	-		$	-

The Company recorded valuation allowances of $379,000 and $176,000 at October 31, 2009 and October 31, 2008, respectively, fully offsetting estimated deferred tax benefits, as management is unable to determine that these tax benefits are more likely than not to be realized.

The tax effects of temporary differences that give rise to significant portions of the deferred tax assets are as follows:

	October 31, 2009		October 31, 2008
Net operating loss carryforwards	$	379,000	$	223,000
Temporary difference:Capitalized interest		-		(47,000	)

	$	379,000	$	176,000

F-12

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Note 8 – Recent Accounting Pronouncements

In May 2009, FASB issued ASC 855, Subsequent Events which establishes general standards of for the evaluation, recognition and disclosure of events and transactions that occur after the balance sheet date. Although there is no new terminology, the standard is based on the same principles as those that currently exist in the auditing standards. The standard, which includes a new required disclosure of the date through which an entity has evaluated subsequent events, is effective for interim or annual periods ending after June 15, 2009. The adoption of ASC 855 did not have a material effect on our company’s consolidated financial statements. The Company has evaluated subsequent events through the date of the issuance of the financials. An additional borrowing of $1.2M on the NSES credit facility occurred after the balance sheet date and before the date of issuance. On February 24, 2010, Accounting Standards Update (“ASU”) 2010-09, amended ASC 855. 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.

F-13

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

In April 2008, the FASB issued EITF 07-5, Determining whether an Instrument (or Embedded Feature) is indexed to an Entities Own Stock, which was primarily codified into Topic 815. Topic 815 provides guidance on determining what types of instruments or embedded features in an instrument held by a reporting entity can be considered indexed to its own stock for the purpose of evaluating the first criteria of the scope exception in paragraph 11(a) of SFAS 133, EITF 07-5 was effective for financial statements issued for fiscal years beginning after December 15, 2008. Management has adopted this standard and does not believe the implementation of this standard will have a significant impact on the financial statements of the Company.

In March 2008, the FASB issued Statement No. 161, Disclosures about Derivative Instruments and Hedging Activities, - an amendment of FASB No. 133 which was primarily codified into Topic 815. Topic 815 requires additional disclosures about the objectives for using derivative instruments and hedging activities, method of accounting for such instruments under Topic 815 and it’s related interpretations, the effect of derivative instruments and related hedged items on financial position, results of operations, and cash flows, and a tabular disclosure of the fair values of derivative instruments and their gains and losses. Management has adopted this standard. See Note 10.

Note 9 – Credit Agreements

On May 29, 2008 the Company closed a $2,500,000 securities purchase agreement with a private investor. Under the agreement, the Company has authorized a series of convertible notes of the Company which are convertible into the Company’s common stock, par value $0.0001 per share. The note bears interest of a 360-day year with the first interest payment due August 29, 2008 and the first principal installment was due May 29, 2009. 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 Note proceeds were used for operating purposes of the Company. The Company incurred closing costs of approximately $651,000 which will be amortized over the term of the note.

One 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 $5,650,000 as of October 31, 2009. 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. Interest is to accrue starting on the day the loan is funded, and the first interest payment was due October 2008. 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 in noncompliance of loan covenants at October 31, 2009. The Company’s working capital ratio is less than one-to-one, which is a breach of the loan covenants. 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.

F-14

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Note 10 – Derivative Liabilities, Beneficial Conversion Feature, Convertible Debt, and Warrants

As of October 31, 2009 and October 31, 2008, the Company recognized derivative liabilities of $1,015,971 and $1,723.453 respectively, and a convertible debt liability, net of discounts of $1,527,780 and $2,152,778, of $972,220 and $347,222, respectively, pursuant to SFAS 133 “Accounting for Derivative Instruments and Hedging Activities” (SFAS 133), primarily codified into Topic 815, relating to a beneficial conversion feature embedded in the Company’s debt instrument entered into on May 29, 2008. The related debt is a convertible 8% senior secured 36 month note dated May 29, 2008 with Institutional Investor. Interest only is payable quarterly. Principal repayments due in 24 equal payments beginning with the 1st year anniversary. This note is convertible into 2,500,000 shares. The conversion feature allows for the conversion of the underlying debt into shares of the Company’s common Stock at a price of $1.50 per share when the market price of the Company’s stock was $2.80 per share. The existence of this discount is called a “beneficial conversion feature.” The purpose of issuing the convertible debt was to raise capital to fund drilling and exploration.

EITF 00-19 “Accounting for Derivative Financial Instruments Indexed to, and Potentially Settled in, a Company’s Own Stock” (EITF 00-19), primarily codified into Topic 815, specifies characteristics that financial instruments to be settled in a Company’s own stock must satisfy in order to be accounted for as equity rather than debt under SFAS 133. Among other provisions, under the EITF, instruments must be categorized as debt if, under terms of the instrument, the Company might be required to issue a variable number of shares in satisfaction of the conversion feature. Provisions of the May 29, 2008 instrument allows net settlement of the instrument upon exercise, resulting in the potential settlement with a variable number of shares, and the settlement is based upon the fixed cash value of the debt, known at issuance.

In connection with the Company’s warrants as discussed in Note 5, the Company incurred initial derivative liabilities totaling $6,300,037 in May 2008. To the extent of proceeds received these liabilities were recorded as a debt discount with any excess expensed upon issuance. Upon early settlement of a loan, any remaining discount is written off. As of October 31, 2009 and October 31, 2008, the unamortized balance of loan fees amounted to $640,694 and $1,005,090.

F-15

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Note 11 Fair Value Measurements

SFAS No. 157, Fair Value Measurements and Disclosures, primarily 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 October 31, 2009, we held certain derivative asset and liability positions that lack level 1 and 2 inputs and are thus required to be measured at fair value on a Level 3 basis.

The fair value of stock warrants is the estimated present value at grant date using the Black-Scholes option-pricing model with the following weighted average assumptions for 2008 and 2009: expected volatility of 60% and 158% respectively, a risk-free interest rate of 4.00% for both 2008 and 2009; and an expected option life remaining from 2.5 to 5 years for both 2008 and 2009.

Note 12 Stockholders’ Equity

The Company has authorized capital stock of 320,000,000 shares consisting of 300,000,000 shares of common stock, $0.0001 par value per share (the “Common Stock”), and 20,000,000 shares of preferred stock with preferences and rights to be determined by the Board of Directors.

The Company has 2,700,000 warrants outstanding at October 31, 2009 and October 31, 2008. The following table summarizes the changes in the company’s outstanding stock based compensation available through warrants for the year ended October 31, 2009 and October 31, 2008:

	Number of Stock		Weighted
	Options Available		Average
	Through Warrants		Exercise Price
Outstanding at beginning of period		-		-

Granted		4,700,000		1.27
Exercised		2,000,000		1.00
Cancelled/forfeited		-		-
Outstanding at October 31, 2009 and 2008		2,700,000		1.46
Options Exercisable at October 31, 2009 and 2008		2,700,000		1.46

The following table summarizes the information respecting stock options available through warrants outstanding and exercisable at October 31, 2009 and October 31, 2008:

F-16

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Stock Options Outstanding								Stock Options Exercisable
Exercise Price		Number Outstanding		Weighted Average Remaining Life		Weighted Average Exercise Price		Number Exercisable		Weighted Average Remaining Contractual Life		Weighted Average Exercise Price
$	1.00		200,000		0.08	$	1.00		200,000		0.08	$	1.00
$	1.50		2,500,000		3.00	$	1.50		2,500,000		3.00	$	1.50

The weighted average fair value per share of options granted during 2008 was $1.34, calculated using the Black-Scholes Option-Pricing model. No options were granted in 2009.

Interest expense of $128,187 related to stock warrants was recognized in 2008.

No warrants were issued at October 31, 2009 or for the period then ended.

Note 13 – Subsequent Events

On December 17, 2009, the Company borrowed an additional $1.2 million on the $10M NSES Credit Facility which brings the total amount borrowed to $6.85 million with a remaining $3.15 million available on the credit facility.

Note 14 – Contingency

By terms of its assignment from K&D enterprises, the Company is required to drill 12 wells per year on the K&D Leasehold. Current estimates are that the cost to drill each well will be in the range of $165,000 to $225,000, for an estimated maximum total of approximately $2.7 million each year. The Company currently does not have the funds to complete these drillings over the expected life of the K&D Assignments and will require additional funds to do so. In the event that 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. Management believes that the possibility of this contingent loss is remote, and, accordingly, no provision has been made in these financial statements for such a loss.

F-17

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Note 15 – Supplemental Natural Gas Information (Unaudited)

Information with respect to the Company’s natural gas producing activities is presented in the following tables. Estimates of reserve quantities, as well as future production and discounted cash flows before income taxes, were developed from information provided by Glenn Robinson – Robinson Engineering utilizing information provided by management as of October 31, 2009 and October 31, 2008.

Gas Related Costs

The following table sets forth information concerning costs related to the Company’s gas property acquisition, exploration and development activities in the United States during the periods.

	October31,2009		October31,2008
Property acquisitions:
Proved	$		$
Unproved		-		-
Less proceeds from sales of properties		-		-
Development cost		3,912,460		2,076,623

Total	$	3,912,460	$	2,076,623

Results of Operations from Gas Producing Activities

As of October 31, 2009 and October 31, 2008, the Company was still in an exploratory stage and had not begun producing activities.

F-18

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

Natural Gas Reserves

The following table sets forth the Company’s net proved gas reserves from inception to October 31, 2009. The changes in net proved gas reserves for the year then ended.

Balance, October 5, 2007 (inception)	Gas MMcf
Revisions of previous estimates		-
Purchase of Reserves in Place		26,657
Proved reserves at October 31, 2007		26,657
Revisions of previous estimates		(1,107	)
Sales of Reserves in Place		-
Proved reserves at October 31, 2008		25,550
Revisions of previous estimates		-
Proved reserves at October 31, 2009		25,550

Proved reserves represent the quantities of natural gas which geological and engineering data demonstrate with reasonable certainty to be recoverable in the future years from known reservoirs under existing economic and operating conditions. Reserves are measured in units of one thousand cubic feet (Mcf) or one million cubic feet (MMcf) in the case of gas.

At October 31, 2009 1,825 thousand Mcf of gas reserves were classified as proved developed reserves, and the balance of the proved reserves, or 23,725 thousand Mcf of gas reserves were classified as proved undeveloped. Proved developed oil and gas reserves are reserves that can be expected to be recovered through existing wells with existing equipment and operating methods.

Standardized Measure of Discounted Future Net Cash Flows

The standardized measure of discounted future net cash flows from the Company’s proved gas reserves is presented in the following tables:

F-19

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

	10/31/2009			10/31/2008
	Amount in Thousands			Amount in Thousands
Future cash inflow	$	98,128		$	129,922
Future production costs and taxes		(4,906	)		(10,696	)
Future development costs		(12,570	)		(11,550	)
Processing, metering and gathering		(23,826	)		(25,984	)
Future income tax expenses		(19,626	)		(25,984	)
Net future cash flows		37,200			55,708
10% Discount		(15,294	)		(24,216	)
Discounted future net cash flows from proved reserves		21,906			31,492
Less portion attrible to NSES ownership		(1,752	)		(2,519	)
Discounted future net cash flows from proved reserves	$	20,154		$	28,973

Standardized Measure of Discounted Future Net Cash Flows

Estimated future net cash flows represent an estimate of future net revenues from the production of proved reserves using current sales prices, along with estimates of the operating costs, production taxes, and future development and abandonment costs (less salvage value) necessary to produce such reserves. The average price used at October 31, 2009 and October 31, 2008 was $5.04 and $6.78 per MCF of gas. No deduction has been made for depreciation, depletion or any indirect costs such as general corporate overhead or interest expense.

Operating costs and production taxes are estimated based on estimated current costs with respect to producing properties. Future Development costs are based on the best estimate of such costs assuming current economic and operating conditions.

The future net revenue information assumes no escalation of costs or prices. Future costs and prices could significantly vary from current amounts and, accordingly, revisions in the future could be significant.

The Properties

The Company’s mineral rights were obtained through three farm-out assignments. Pursuant to the assignments, as supplemented and corrected, the Company is entitled to all working rights to, and a 75% net revenue interest in, the hydrocarbons in the New Albany Shale (Devonian), less a 6% overriding royalty interest owned by NSES, LLC. Under the Assignments the Company has the right to drill wells on the properties and extract from these wells and sell the natural gas found in the New Albany shale formation running through the properties. Pursuant to the Assignments, the Company is required to drill 12 wells per year within the properties in order to retain its farmed-in rights.

F-20

KENTUCKY USA ENERGY

(Formerly Las Rocas Mining Corp.)

(AN EXPLORATION STAGE COMPANY)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

October 31, 2009

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 are excluded from the costs being amortized. No ceiling write-downs were recorded during the year ended October 31, 2009 and October 31, 2008.

F-21

Kentucky USA Energy, Inc. 10-K/A