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EX-23.1 - CIRCLE STAR ENERGY CORP.ex23-1.htm
EX-23.3 - CIRCLE STAR ENERGY CORP.ex23-3.htm
EX-23.2 - CIRCLE STAR ENERGY CORP.ex23-2.htm
EX-21.1 - CIRCLE STAR ENERGY CORP.ex21-1.htm
EX-10.29 - CIRCLE STAR ENERGY CORP.ex10-29.htm
FILE NO. 333-184364

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 

 
FORM S-1
(Amendment No. 1)
REGISTRATION STATEMENT UNDER THE SECURITIES ACT OF 1933
 

 
CIRCLE STAR ENERGY
(Exact name of registrant as specified in its charter)
 
Nevada
 
1311
 
30-0696883
(State or other jurisdiction of
incorporation or organization)
 
(Primary Standard Industrial
Classification Code Number)
 
(I.R.S. Employer Identification No.)
 
7065 Confederate Park Road, Suite 102
Fort Worth, Texas 76108
(817) 744-8502
(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)
 
Dorsey & Whitney LLP
1400 Wewatta Street
Suite 400
Denver, Colorado 80202
(303) 629-3400
(Name, address, including zip code, and telephone number, including area code, of agent for service)
 
Copies to:
 
Kenneth G. Sam, Esq.
James B. Guttman, Esq.
Dorsey & Whitney LLP
1400 Wewatta Street, Suite 400
Denver, Colorado 80202

Approximate date of commencement of proposed sale to the public:  As soon as practicable after this registration statement becomes effective
 
If any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933 check the following box: x
 
If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier registration statement for the same offering. o
 
If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o
 
If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. o
 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company.  (Check one):
 
Large Accelerated Filer o                                         Accelerated Filer o                                 Non-Accelerated Filer o                                     Smaller Reporting Company x

 
CALCULATION OF REGISTRATION FEE
 
Title of each class of securities to be registered
 
Proposed maximum aggregate
offering price
   
Amount of
registration fee
 
Units, each consisting of ● share(s) of Common Stock, $0.001 and ● Common Stock Warrant(s)
               
Shares of Common Stock included as part of the units
               
Common Stock Warrants included as part of the units
               
Shares of Common Stock acquirable upon exercise of the Common Stock Warrants
               
Shares of Common Stock acquirable
               
TOTAL
 
$
7,000,000
   
$
954.80 *
 
 
*Previously Paid
 
 
The Registrant hereby amends this Registration Statement on such date or dates as may be necessary to delay its effective date until the Registrant shall file a further amendment which specifically states that this Registration Statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933, as amended (the “Securities Act”), or until this Registration Statement shall become effective on such date as the Commission, acting pursuant to said Section 8(a), may determine.
 
 
 
 
 
 
 
The information contained in this prospectus is not complete and may be changed.  We may not sell these securities until the registration statement filed with the Securities and Exchange Commission is effective.  This prospectus is not an offer to sell these securities and we are not soliciting an offer to buy these securities in any state where the offer or sale is not permitted.
 
Subject To Completion:  Dated       , 2013
 
PRELIMINARY PROSPECTUS
 
Circle Star Energy Corp.
 
$7,000,000
[●] Units
Each Unit Consisting of [●] Share(s) of Common Stock
and [●] Common Stock Warrant(s)

We are offering [●] units, each unit consisting of [●] share(s) of common stock, $0.001 par value (a “Share”) and [●] common stock warrant(s) (a “Warrant”) at a public offering price of $[●] per unit (a “Unit”).  The Warrants will become exercisable and separately transferable from the Shares commencing [●] calendar days after the date of this prospectus.  At any time until [●] years following the date of this prospectus, each Warrant entitles the holder to purchase [●] Share(s) at an exercise price of $[●], subject to adjustment.

Our common stock is currently listed on the Over-the-Counter Bulletin Board under the symbol “CRCL”.  As of January 11, 2013 the last reported sale price of our common stock was $0. 35 per share on the Over-the-Counter Bulletin Board.
 
We have retained Ladenburg Thalmann & Co. Inc. (the “Placement Agent”) to act as our exclusive Placement Agent in connection with this offering until the expiration date of the offering.  We intend to enter into a Placement Agency Agreement with the Placement Agent, relating to the units offered by this prospectus.  The Placement Agent is not purchasing or selling any of our units pursuant to this prospectus but will use its best efforts to sell the units being offered.   Therefore, we will enter into a purchase agreement directly with investors in connection with this offering and confirmations and definitive prospectuses will be delivered, or otherwise made available, to all purchasers who agree to purchase units, informing the purchasers of the closing date as to such units.  We have agreed to pay the Placement Agent a placement agent fee equal to 8% of the aggregate gross proceeds to us from the sale of the units.  See “Plan of Distribution” beginning on page 56 of this prospectus for more information regarding this arrangement.
 
Investing in our common stock involves a high degree of risk.  You should read this entire prospectus carefully, including the section entitled “Risk Factors” beginning on page 4.
 
   
Per Unit
   
Total
 
             
Public offering price
  $       $    
Placement Agent’s fees (1)
  $       $    
Proceeds to us, before expenses (2)
  $       $    
 
 
(1) For the purpose of estimating the placement agent’s fees, we have assumed that they will receive their maximum commission on all sales made in the offering. We have agreed to reimburse the Placement Agent’s expenses in an amount not to exceed the lesser of  (i) 2.5% of the aggregate gross proceeds raised in the offering or (ii) $60,000.

(2) We estimate the total expenses of this offering, excluding the placement agent fees, will be approximately $[●]. Because there is no minimum offering amount required as a condition to closing in this offering, the actual public offering amount, placement agent fees, and proceeds to us, if any, are not presently determinable and may be substantially less than the total maximum offering set forth above. Once the offering price has been determined, the common stock offering price and warrant exercise price will remain fixed for the duration of the offering.  See “Plan of Distribution” beginning on page 56 of this prospectus for more information on this offering and the placement agent arrangements.

This offering will terminate on [●], 2013, unless the offering is fully subscribed before that date or we decide to terminate the offering prior to that date. In either event, the offering may be closed without further notice to you.  We except that delivery of the units being offered pursuant to this prospectus will be made to the purchasers on or about [●] 2013.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined if this prospectus is truthful or complete.  Any representation to the contrary is a criminal offense.

(Ladenburg Thalmann& Co. Inc.)
 
 
The date of this prospectus is    , 2013
 
 
TABLE OF CONTENTS
 

You should rely only on the information contained or incorporated by reference in this prospectus and in any free writing prospectus that we have authorized for use in connection with this offering.  Neither we nor Ladenberg Thalmann & Co. Inc. has authorized any other person to provide you with additional or different information.  If anyone provides you with different or inconsistent information, you should not rely on it.  Neither we nor Ladenberg Thalmann & Co. Inc. is making an offer to sell these securities in any jurisdiction where an offer or sale is not permitted.  You should assume that the information in this prospectus is accurate only as of the date on the front cover of this prospectus, regardless of the time of delivery of this prospectus or any sale of our common stock.  Our business, financial condition, results of operations and prospects may have changed since that date.
 
Some of the industry and market data contained in this prospectus are based on independent industry publications or other publicly available information, while other information is based on our internal sources.  Although we believe that each source is reliable as of its respective date, the information contained in such sources has not been independently verified, and neither we, nor Ladenberg Thalmann & Co. Inc. can assure you as to the accuracy or completeness of this information.
 
 
 
This summary highlights information contained elsewhere in this prospectus and does not contain all of the information you should consider before buying shares of our common stock.  You should read the entire prospectus carefully, especially the “Risk Factors” section and our consolidated financial statements and the related notes appearing at the end of this prospectus, before deciding to invest in shares of our common stock.  Unless the context provides otherwise, all references to “Circle Star,” “we,” “us,” “our,” or similar terms, refer to Circle Star Energy Corp. and its wholly owned subsidiaries.
 
In this prospectus all references to “$” or “dollars” mean the U.S. dollar, and unless otherwise indicated all currency amounts in this prospectus are stated in U.S. dollars.  All financial statements have been prepared in accordance with accounting principles generally accepted in the United States and are reported in U.S. dollars.
 
The Company

We are an oil and gas exploration and production company whose shares are traded over-the-counter. Based in Fort Worth, Texas, we own producing and non-producing oil and gas mineral interests, royalty interests, and working interest located throughout Texas. Our focus is on acquiring and developing oil and gas interests targeting commercial reserves in Texas and Kansas.

Producing Assets:
·  
Madisonville Woodbine Field (Madison/Grimes, County, Texas) – Woodbine
·  
Pearsall Field (Dimmit/Zavala County, Texas) – Austin Chalk , Eagle Ford Shale
·  
Permian Basin (Scurry/Crane/Glasscock et. al. County, Texas) – Wolfcamp, Clearfork, Spraberry, Fusselman, Cline Shale

Operators:
·  
Apache Corp. - NYSE: APA
·  
Chesapeake Energy – NYSE: CHK
·  
CML Exploration (formerly Patterson Exploration) – Private company
·  
Leexus Oil & Gas– Private company
·  
Woodbine Acquisition Corp.- Private company

Our continued focus will be on acquiring and developing oil and gas assets in Northwest Kansas.

Leadership
 
S. Jeffrey Johnson (Chief Executive Officer and Chairman)

Mr. Johnson has served as one of our directors since June 2011 and as Chairman of the Board of our Board of Directors since July 2011. He was named Chief Executive Officer of the Company in November 2011. Mr. Johnson’s affiliation with the Company began when we acquired a private oil and gas company that he owned and was a managing member of . Mr. Johnson was the founder, Chairman and CEO of Cano Petroleum, Inc. (formerly NYSE MKT:CFW) from 2004-2011, a publicly traded oil and gas E&P company focused on producing oil in the mid-continent region of the United States. Cano Petroleum, Inc. had various interests in properties in Texas, Oklahoma and New Mexico. He founded Cano Petroleum, Inc. in 2004 and took it public initially as an OTC listed company with a market capitalization of approximately $15 million and net production of approximately three barrels of oil per day. In 2005, Cano Petroleum, Inc. was listed on the NYSE MKT exchange. In 2008, Cano Petroleum, Inc. had a peak market capitalization of approximately $350 million and was producing approximately 1,900 barrels of oil equivalent per day. Between 1993 and 2004, Mr. Johnson was the founder and CEO of several privately-held, Texas-based oil and gas companies, including Scope Operating Company and Acumen Resources, Inc. In 1989, Mr. Johnson began his career as the Vice President of Touchstone Capital, a company that raised capital for drilling programs for Chesapeake Energy Corporation (NYSE:CHK), when it was a privately-held company. Mr. Johnson previously served as a member of the NYSE/AMEX Listed Company Council for three years which is an advisory board consisting of senior executives of the Exchange’s listed companies.
 
 
G. Jonathan Pina (Chief Financial Officer)
 
Mr. Pina brings a range of oil and gas finance and transaction experience, having advised public and private companies engaged in conventional exploration and production, unconventional resource development, liquefied natural gas (LNG) commercialization, midstream operations, crude refining, and oilfield services.  From 2008 to just prior to joining the Company, Mr. Pina was the Managing Partner and co-founder of Pimuro Capital Partners, a boutique financial advisory firm dedicated to publicly traded, emerging-growth companies in the Energy sector.   From 2007 to 2008, Mr. Pina led the Energy group at Chiron Financial Advisors, an Investment Banking firm in Houston that provided merchant banking, capital raising and advisory services to public and private Oil & Gas companies.  Mr. Pina began his career by working in the Houston office of the Energy Investment Banking Group at Jefferies Inc.   Mr. Pina received a Bachelor of Arts degree from Rice University in 2003 and a Master of Business Administration from the Jesse H. Jones School of Management at Rice University in 2005.  Mr. Pina was selected as the 2008 Emerging Businessman of the Year (Houston Hispanic Chamber of Commerce) and he is a member of the Association of Corporate Growth, the Turnaround Management Association and the Houston Hispanic Chamber of Commerce.

Jayme Wollison (Vice President of Operations)

Mr. Wollison has spent the last 38 years in the oil and gas business and is a third-generation oil and gas driller and producer. He has extensive drilling, water flood, well service and facility experience in the Mid-Continent and Permian Basin regions of North America.  Prior to working for Circle Star Energy Corp., he was the Director of Operations for Cano Petroleum, Inc. (formerly NYSE MKT:CFW) from 2004-2011, a publicly traded oil and gas E&P company focused on producing oil in the mid-continent region of the United States.  From 1980 to 2004, he owned and operated several privately-held oil and gas production and services companies with production assets in Oklahoma and Kansas, where he successfully drilled and put into production over 100 Mississippian wells.  One of these companies, Ladder Energy was sold to Cano Petroleum Inc.  He also owned and operated Patriot Petroleum, another privately-held oil and natural gas producer that was sold to a private company in 2004.  Mr. Wollison was the Founder and CEO of Stratford Well Services Company, a privately-held oilfield services company that provided drilling rig and roustabout services.

Elmer Reed (Director)

Mr. Reed has over four decades of oil field service & operational experience.  Mr. Reed is currently Vice President, Executive Sales for Select Energy Services, a privately-held oil field services company that has over $1 billion in revenues, more than 5,000 employees, and provides services to more than 400 customers in every major shale play throughout the United States and Canada.  Mr. Reed previously worked as the Senior Sales Manager for BJ Services Company (formerly NYSE:BJS), a Texas-based provider of pressure pumping and oilfield services for the petroleum industry.  BJ Services Company was bought by Baker Hughes Incorporated (NYSE:BHI) in 2009 for $5.5 Billion.  Mr. Reed also worked at Newpark Drilling Fluids, a division of Newpark Resources Inc. (NYSE:NR), where he served as the Executive Sales Manager.  Newpark Resources Inc. provides drilling fluid products and technical services to companies in North America, Brazil, Europe and North Africa.  Mr. Reed spent 28 years with Halliburton Energy Services, a division of Halliburton Company (NYSE:HAL), where his last management role was of Business Development Manager, where he reported directly to the President.  During his time with Halliburton, Mr. Reed spent time overseeing projects through South America, Mexico, Russia and parts of Europe.  Mr. Reed has served as Director and Secretary and Treasurer of the International Oilmen’s Golf Association for over 30 years. Mr. Reed is active in IPAA and is a lifetime member of Society of Petroleum Engineers, Houston Livestock Show and Rodeo, and Houston Farm and Ranch.  Mr. Reed is a graduate of Texas Tech University with a BBA in Management.

Thomas Merrill Richards (Director)

Mr. Richards is the Managing Member of Tom M Richards & Associates, a law firm servicing oil and gas companies focused on the mid-continent region, and the Managing Partner and Owner of Richards Cattle Company, a privately-held working ranch in West Texas.  Between 2008 and 2010, he served as the Land and Lease Manager of Cano Petroleum, Inc., (formerly NYSE MKT:CFW), a publicly traded oil and gas E&P company focused on producing oil in the mid-continent region of the United States.  Mr. Richards graduated with a B.A. in Finance at Texas Tech University and earned his Doctorate of Law at Baylor University.  Between 1986 and 1990 he was a member of the Chancellor's Council at Texas Tech University, an advisory board of alumni that provides leadership support for the University by funding student scholarships and faculty awards.  Mr. Richards is the Founder and President of “Books for Belize”, a Texas company that provides children’s books to Central America Countries.
 
 
Morris “Sam” B. Smith (Director)

Mr. Smith is the former CEO and Director of Woodbine Acquisition Corporation, a privately-held oil and natural gas company focused on the acquisition, development, and exploitation of crude oil and natural gas properties in Texas.  He is also the former CFO of Cano Petroleum, Inc., (formerly NYSE MKT:CFW), a publicly traded oil and gas E&P company focused on producing oil in the mid-continent region of the United States.  He previously served as the CFO of Encore Acquisition Co. (formerly NYSE:EAC), a company engaged in oil and natural gas acquisitions and development and acquired by Denbury Resources Inc. (NYSE:DNR) for $4.3 billion.  He is the former CFO for Union Pacific Resources Group (NYSE:UPR) an oil and gas company that was spun out Union Pacific Corporation (NYSE:UNP) in 1995.  Union Pacific Corporation merged with Anadarko Petroleum Corporation (NYSE:APC) in 1999.  He was the former Financial Controller for Union Pacific Corporation (NYSE:UNP), a railroad transportation company with 44,000 employees and covering 23 states across the western two-thirds of the United States.  Mr. Smith has a B.B.A. in Accounting from McMurry University and Advanced Management Program from Harvard.
 
The Offering
 
Units:
 
Units offered
[●] Units, at $[●] per Unit
 
 
Each Unit consists of [●] share(s) of common stock, $0.001 par value (a “Share”), and [●] common stock warrant(s) (a “Warrant”).
 
Common Stock:
 
Common stock offered
[●] shares
 
Common stock outstanding before the offering (1)
[42,304,571] shares
 
Common stock outstanding after the offering (2)
[●] shares
 
Quoting
Our common stock is currently listed on the Over-the-Counter Bulletin Board under the symbol “CRCL”.
Warrants:
 
Exercisability
Each Warrant is exercisable for [●] share(s) of common stock.
 
Exercise Price
$[●]
 
Exercise Period
The Warrants become exercisable [●] days from the date of this prospectus.
 
The Warrants will expire at [●] p.m., [●] time, on [●].
 
Use of Proceeds:
The net proceeds from the sale of the common stock in this offering are estimated to be approximately $6,291,510 after deducting the Ladenberg Thalmann & Co. Inc.’s commissions and fees and estimated offering expenses.  We intend to use the net proceeds from this offering to acquire properties in western Kansas, to fund drilling programs in western Kansas, to fund working capital needs and other general corporate purposes and to retire certain accounts payable, accrued expenses and other short-term liabilities.
Risk Factors:
Investing in our common stock involves risks that are described in the “Risk Factors” section beginning on page 6 of this prospectus.
   

(1)
Based on the number of shares outstanding as of [●]. Does not include the following currently exercisable or convertible outstanding securities: 116,666 shares of common stock issuable upon exercise of currently exercisable options to purchase our common stock, 250,000 shares issuable upon exercise of currently exercisable warrants to purchase our common stock, and 3,444,444 shares issuable upon the conversion of $4,387,500 in aggregate principal amount of our convertible debentures and notes.
 
(2)
Based on the number of shares outstanding as of [●], plus the [●] Shares offered as part of the Units under this prospectus. Does not include the following currently exercisable or convertible outstanding securities: 116,666 shares of common stock issuable upon exercise of currently exercisable options to purchase our common stock, 250,000 shares issuable upon exercise of currently exercisable warrants to purchase our common stock, and 3,444,444 shares issuable upon the conversion of $4,387,500 in aggregate principal amount of our convertible debentures and notes. Also excludes [●] shares of common stock issuable upon exercise of the Warrants offered as part of the Units under this prospectus.

 
RISK FACTORS
 
An investment in our common stock involves a high degree of risk.  You should carefully consider the risk factors described below together with all of the other information contained in this prospectus, including our consolidated financial statements and the notes thereto, before deciding whether to invest in shares of our common stock.  Each of these risks could have a material adverse effect on our business, operating results, financial condition and/or growth prospects.  As a result, the trading price of our common stock could decline and you might lose all or part of your investment.  Additional risks and uncertainties not presently known to us or that we currently deem immaterial may also impair our operations.
 
Much of the information included in this registration statement includes or is based upon estimates, projections or other "forward looking statements".  Such forward looking statements include any projections or estimates made by us and our management in connection with our business operations.  While these forward-looking statements, and any assumptions upon which they are based, are made in good faith and reflect our current judgment regarding the direction of our business, actual results will almost always vary, sometimes materially, from any estimates, predictions, projections, assumptions or other future performance suggested herein.

Such estimates, projections or other "forward looking statements" involve various risks and uncertainties as outlined below.  We caution the reader that important factors in some cases have affected, and in the future could materially affect actual results and cause actual results to differ materially from the results expressed in any such estimates, projections or other "forward looking statements".

Risk Factors Relating to Our Company

We will need significant additional capital, which we may be unable to obtain.

Our capital requirements in connection with our early stage activities and transition to commercial operations have been and will continue to be significant. We estimate our contractual obligations from December 1, 2012 to April 30, 2013 to be approximately $2,935,000 .  We anticipate we will fund these obligations by issuing equity and/or debt securities. There can be no assurance that financing will be available in amounts or on terms acceptable to us, if at all.  There is no assurance additional funds will be available from any source; or, if available, such funds may not be on terms acceptable to us.  In either of the aforementioned situations, we may not be able to fully implement its growth plans.

We may not be able to effectively manage the demands required of a new business in our industry, such that we may be unable to successfully implement our business plan or achieve profitability.

We have earned limited revenues to date and we have never been profitable. Our current business strategy is to grow through acquisitions of oil and gas properties. We may not be able to effectively execute our business plan or manage growth, if any, of our business. Future development and operating results will depend on many factors, including access to adequate capital, the demand for oil and gas and price competition. Many of these factors are beyond our control. In addition, our future prospects must be considered in light of the risks, expenses and difficulties frequently encountered in establishing a new business in the oil and gas industry, which is characterized by intense competition, rapid technological change, and significant regulation. If we are unable to address these matters, or any of them, then we may not be able to successfully implement our business plan or achieve profitability.

Because we have earned limited revenues from operations, all our capital requirements have been met through financing and we may not be able to continue to find financing to meet our operating requirements.

We will need to obtain additional financing in order to pursue our business plan. As of April 30, 2012 we had cash on hand of $60,626 and a working capital deficit $3,163,141. As of October 31, 2012 we had cash on hand of $66,988 and a working capital deficit $3,371,222 .  We estimate we will require approximately $3,000,000 during the next twelve months to fund development costs, corporate overhead, payment of debt and payment of all other of our contractual obligations. As such, we estimate that we will need to raise additional funds to fund our planned operations over the next twelve months. We may not be able to obtain such financing at all or in amounts that would be sufficient for us to meet our current and expected working capital needs. It is not anticipated that any of our officers, directors or current stockholders will provide any significant portion of our financing requirements. Furthermore, in the event that our plans change, our assumptions change or prove inaccurate, we could be required to seek additional financing in greater amounts than is currently anticipated. Any inability to obtain additional financing when needed would have a material adverse effect on us, including possibly requiring us to significantly curtail or possibly cease our operations. In addition, any future equity financing may involve substantial dilution to our existing stockholders.
 

Our auditors have expressed substantial doubt about our ability to continue as a going concern.

Our audited financial statements for the years ended April 30, 2012 and 2011 have been prepared assuming that we will continue as a going concern.  Since inception to October 31, 2012, we have incurred an accumulated net loss of $19,054,400 and our auditors have expressed substantial doubt about our ability to continue as a going concern. Our financial statements do not include any adjustments that might result from the outcome of this uncertainty.

Because we have a history of losses and anticipate continued losses unless and until we are able to generate sufficient revenues to support our operations, we may lack the financial stability required to continue operations.

Since inception we have suffered recurring losses. The current level of oil and gas production from our assets is not sufficient to completely fund our budget or working capital requirements going forward, such that we will require additional financing in order to pursue our plan of operations. We anticipate that our losses will continue until such time, if ever, as we are able to generate sufficient revenues to support our operations. Our ability to generate revenue primarily depends on the success in developing the properties we have an interest in and our ability to acquire new assets. If the properties do not attain sufficient revenues or do not achieve profitable operations, our business may fail.

Oil and gas resources on all properties may not continue to be commercially viable, which would cause our business to fail.

We may not be able to achieve commercial production at a level that will be sufficient to pay drilling and completion costs. In addition, the cost of drilling, completing and operating wells is often uncertain. Drilling operations on our properties or on properties we may acquire in the future may be curtailed, delayed or cancelled as a result of numerous factors, including title problems, weather conditions, compliance with governmental requirements and shortages or delays in the delivery of equipment. Furthermore, completion of a well does not assure a profit or a recovery of drilling, completion and operating costs. As a result, our business, results of operations and financial condition may be materially adversely affected.

Actual production, revenues and expenditures with respect to reserves will likely vary from estimates, which could have a material adverse effect on our business, results of operations and financial condition.

There are numerous uncertainties inherent in estimating oil and gas reserves and their estimated values, including many factors beyond the control of the producer. Reservoir engineering is a subjective process of estimating underground accumulations of oil and gas that cannot be measured in an exact manner. Estimates of economically recoverable oil and gas reserves and of future net cash flows necessarily depend upon a number of variable factors and assumptions, such as historical production from the area compared with production from other producing areas, the assumed effects of regulations by governmental agencies and assumptions concerning future oil and gas prices, future operating costs, severance and excise taxes, development costs and work-over and remedial costs, all of which may in fact vary considerably from actual results. For these reasons, estimates of the economically recoverable quantities of oil and gas attributable to any particular group of properties, classifications of such reserves based on risk of recovery, and estimates of the future net cash flows expected therefrom prepared by different engineers or by the same engineers but at different times may vary substantially, and such reserve estimates may be subject to downward or upward adjustment based upon such factors. Actual production, revenues and expenditures with respect to reserves will likely vary from estimates, when and if made, and such variances may be material, which could have a material adverse effect on our business, results of operations and financial condition.

Future oil and gas production from our properties is highly dependent upon the ability to find or acquire reserves.
 
In general, the volume of production from oil and gas properties declines as reserves are depleted, with the rate of decline depending on reservoir characteristics. Except to the extent oil and gas operators conduct successful development activities or we acquire properties containing proved reserves, or both, our proved reserves, if any, will decline as reserves are produced. Our future oil and gas production is, therefore, highly dependent upon our level of success in developing or acquiring additional oil and gas reserves. The business of developing or acquiring reserves is capital intensive. To the extent cash flow from operations is reduced and external sources of capital become limited or unavailable, our ability to make the necessary capital investment to maintain or expand our asset base of oil and gas reserves would be impaired. The failure of an operator of our wells to adequately perform operations, or such operator’s breach of the applicable agreements, could adversely impact us. In addition, we may not obtain additional proved reserves or be able to drill productive wells at acceptable costs, in which case our business would fail.
 

Oil and gas resources may contain certain hazards which may, in turn, create certain liabilities or prevent the resources from being commercially viable.

Our properties may contain hazards such as unusual or unexpected formations and other conditions. Projects on our properties may become subject to liability for pollution, fire, explosion, blowouts, cratering and oil spills, against which we cannot or will not insure. Such events could result in substantial damage to oil and gas wells, producing facilities and other property and/or result in personal injury. Costs or liabilities related to those events would have a material adverse effect on our business, results of operations, financial condition and cash flows.

Oil and gas prices are highly volatile, and a decline in oil and gas prices could have a material adverse effect on our business, results of operations, financial condition and cash flows.

Oil and gas prices and markets are highly volatile. Prices for oil and gas are subject to significant fluctuation, market uncertainty and a variety of additional factors. Our profitability will be substantially dependent on prevailing prices for gas and oil. The amounts of and prices obtainable for our oil and gas production may be affected by market factors beyond our control, such as:
 
the extent of domestic production;
the amount of imports of foreign oil and gas;
the market demand on a regional, national and worldwide basis;
domestic and foreign economic conditions that determine levels of industrial production;
political events in foreign oil-producing regions; and
variations in governmental regulations and tax laws or the imposition of new governmental requirements upon the oil and gas industry.

These factors or any one of them could result in the decline in oil and gas prices, which could have a material adverse effect on our business, results of operations, financial condition and cash flows.
 
The oil and gas market is heavily regulated, and existing or subsequently enacted laws or regulations could limit our production, increase compliance costs or otherwise adversely impact our operations or revenues.

Properties in which we own an interest are subject to various federal, state and local laws and regulations. These laws and regulations govern safety, development, taxation and environmental matters that are related to the oil and gas industry. To conserve oil and gas supplies, regulatory agencies may impose price controls and may limit production. Certain laws and regulations require drilling permits, govern the spacing of wells and the prevention of waste and limit the total number of wells drilled or the total allowable production from successful wells. Other laws and regulations govern the handling, storage, transportation and disposal of oil and gas and any by-products produced in oil and gas operations. These laws and regulations could materially adversely impact our revenues.

Laws and regulations that affect oil and gas operators may change from time to time in response to economic or political conditions. Thus, they must also consider the impact of future laws and regulations that may be passed in the jurisdictions where our properties are located. We anticipate that future laws and regulations related to the oil and gas industry will become increasingly stringent and cause oil and gas operators to incur substantial compliance costs, which may adversely affect their operations.

The nature of the operations on our properties exposes us to environmental liabilities.

The operations on the properties can create the risk of environmental liabilities. Although, currently, we do not serve as an operator on our properties, our operating partners may incur liability to governments or to third parties for any unlawful discharge of oil, gas or other pollutants into the air, soil or water, which could potentially discharge oil or gas into the environment in any of the following ways:
 
from a well or drilling equipment at a drill site;
from a leak in storage tanks, pipelines or other gathering and transportation facilities;
from damage to oil or gas wells resulting from accidents during normal operations; or
from blowouts, cratering or explosions.
 
 
Environmental discharges may move through the soil to water supplies or adjoining properties, giving rise to additional liabilities. Some laws and regulations could impose liability for failure to obtain the proper permits for, to control the use of, or to notify the proper authorities of a hazardous discharge. Such liability could have a material adverse effect on our financial condition and our results of operations and could possibly cause our operations to be suspended or terminated on such property.
 
We could lose or fail to attract the personnel necessary to run our business.
 
Our success depends, to a large extent, on our ability to attract and retain key management and personnel. Jeff Johnson, Jonathan Pina and Jayme Wollison are each key management personnel, which we depend on for our success. As we develop additional capabilities and expand the scope of our business, we will require more skilled personnel. Recruiting personnel for the oil and gas industry is highly competitive. We may not be able to attract and retain qualified executive, managerial and technical personnel needed for our business. Our failure to attract or retain qualified personnel could delay or result in our inability to complete our business plan.
 
Our directors and officers may experience conflicts of interest which may detrimentally affect our profitability.
 
Some of our directors and officers are currently and may also become directors, officers, contractors, shareholders or employees of other companies engaged in oil and natural gas development. To the extent that such other companies may participate in ventures in which we may participate, our directors may have a conflict of interest in negotiating and concluding terms respecting the extent of such participation. In the event that such a conflict of interest arises at a meeting of our directors, a director who has such a conflict will declare his interest and abstain from voting for or against the approval of such participation or such terms. In appropriate cases, we will establish a special committee of independent directors to review a matter in which several directors, or management, may have a conflict. From time to time, several companies may participate in the acquisition, and development of oil and natural gas properties thereby allowing for their participation in larger programs, permitting involvement in a greater number of programs and reducing financial exposure in respect of any one program. A particular company may assign all or a portion of its interest in a particular program to another of these companies due to the financial position of the company making the assignment.

Delays in development or production curtailment affecting our material properties may adversely affect our financial position and results of operations.
 
Depending on the nature of our property interests we may be required to fund our pro rata share of costs related to the development. These costs may be significant. The size of our operations and our capital expenditure budget limits the number of wells that we can develop in any given year. Complications in the development of any single material well may result in a material adverse effect on our financial condition and results of operations.
 
Because of our lack of assets and geographic diversification, adverse developments in the operating area of our properties would adversely affect our results of operations.

Our assets are currently located in the Texas and Kansas and we intend to acquire additional assets in Kansas. As a result, our business is disproportionately exposed to adverse developments affecting these States. These potential adverse developments could result from, among other things, changes in governmental regulation, capacity constraints with respect to the pipelines connected to our wells, curtailment of production, natural disasters or adverse weather conditions in or affecting these States. Due to our lack of diversification in asset type and location, an adverse development in our business or these operating areas would have a significantly greater impact on our financial condition and results of operations than if we maintained more diverse assets and operating areas.

Currently, we do not serve as operator on all of our oil and gas properties, therefore we must rely on our operating partners for the operation of a portion of our properties.

We have acquired less than the controlling working interest in some of our producing oil and natural gas properties, thus those oil and gas properties are not be operated by us. As we do not have controlling interest, the operator or the other co-owners might take actions we do not agree with and possibly increase costs or reduce production income in ways we do not agree with. We are also not responsible for or involved in decisions related to costs, operating efficiencies, personnel, permitting as well as other necessary and important decisions made regarding the properties that we hold a minority interest in.
 

Operations in the oil and natural gas industry subject us to complex laws and regulations that can have a material adverse effect on the cost, manner and feasibility of doing business.

Companies that develop, produce and sell oil and natural gas in the United States are subject to extensive federal, state and local laws and regulations, including complex tax and environmental laws and the corresponding regulations, and are required to obtain various permits and approvals from federal, state and local agencies. If these permits are not issued or unfavorable restrictions or conditions are imposed on our drilling activities, oil and gas operators may not be able to conduct the operations as planned. Oil and gas operators may be required to make large expenditures to comply with governmental regulations. Matters subject to regulation include:
 
water discharge and disposal permits for drilling operations;
drilling bonds;
drilling permits;
reports concerning operations;
air quality, noise levels and related permits;
spacing of wells;
rights-of-way and easements;
unitization and pooling of properties;
gathering, transportation and marketing of oil and natural gas;
taxation; and
waste transport and disposal permits and requirements.

Failure to comply with these laws may result in the suspension or termination of operations and subject us to liabilities under administrative, civil and criminal penalties. Compliance costs can be significant. Moreover, these laws could change in ways that substantially increase the costs of doing business. Any such liabilities, penalties, suspensions, terminations or regulatory changes could materially and adversely affect our business, financial condition and results of operations.

The unavailability or high cost of drilling rigs, equipment, supplies, personnel and oilfield services could adversely affect the cost of operations of our properties or our ability to execute our plans on a timely basis.

Due to drilling activity increases, a general shortage of drilling rigs, equipment, supplies and personnel has developed. As a result, the costs and delivery times to oil and gas operators of rigs, equipment, supplies or personnel are substantially greater than in previous years. From time to time, these costs have sharply increased and could do so again. The demand for and wage rates of qualified drilling rig crews generally rise in response to the increasing number of active rigs in service and could increase sharply in the event of a shortage. Shortages of drilling rigs, equipment, supplies or personnel could delay or adversely affect the development operations, which could have a material adverse effect on our business, financial condition and results of operations.

Risks Relating To Our Common Stock

Our common stock has a limited trading history and has experienced price volatility.

Our common stock trades on the OTC Bulletin Board. The volume of trading in our common stock varies greatly and may often be light, resulting in what is known as a "thinly-traded" stock.  The closing price for our common stock has ranged from $0.16 to $2.38 during our first two fiscal quarters ending October 31, 2012. Until a larger secondary market for our common stock develops, the price of our common stock may fluctuate substantially. The price of our common stock may also be impacted by any of the following, some of which may have little or no relation to our company or industry:
 
the breadth of our stockholder base and extent to which securities professionals follow our common stock;
investor perception of our Company and the oil and natural gas industry, including industry trends;
domestic and international economic and capital market conditions, including fluctuations in commodity prices;
responses to quarter-to-quarter variations in our results of operations;
announcements of significant acquisitions, strategic alliances, joint ventures or capital commitments by us or our competitors;
additions or departures of key personnel;
sales or purchases of our common stock by large stockholders or our insiders;
accounting pronouncements or changes in accounting rules that affect our financial reporting; and
changes in legal and regulatory compliance unrelated to our performance.
 

In addition, the stock market in general and the market for natural gas and oil development companies in particular have experienced extreme price and volume fluctuations that have often been unrelated or disproportionate to the operating results or asset values of those companies. These broad market and industry factors may seriously impact the market price and trading volume of our common shares regardless of our actual operating performance.

We have not paid cash dividends on our common stock and do not anticipate paying any dividends on our common stock in the foreseeable future.

We do not anticipate paying cash dividends on our common stock in the foreseeable future. Payment of future cash dividends, if any, will be at the discretion of our board of directors and will depend on our financial condition, results of operations, contractual restrictions, capital requirements, business prospects and other factors that our board of directors considers relevant. Accordingly, investors may only see a return on their investment if the value of our securities appreciates.

A decline in the price of our common stock could affect our ability to raise further working capital and adversely impact our operations.

A prolonged decline in the price of our common stock could result in a reduction in the liquidity of our common stock and a reduction in our ability to raise capital. Because our operations have been primarily financed through the sale of equity securities, a decline in the price of our common stock could be especially detrimental to our liquidity and our continued operations. Any reduction in our ability to raise equity capital in the future would force us to default on our debt obligations and forfeit our property interests or to reallocate funds from other planned uses.  Either of these would have a significant negative effect on our business plans and operations, including our ability to acquire new property interests or fund our obligations for development of our current property interests. If our stock price declines, we may not be able to raise additional capital or generate funds from operations sufficient to meet our obligations.

Our stock is a penny stock. Trading of our stock may be restricted by the Securities and Exchange Commission's penny stock regulations which may limit a stockholder's ability to buy and sell our stock.

Our stock is a penny stock. The SEC has adopted Rule 15g-9 which generally defines "penny stock" to be any equity security that has a market price (as defined) less than $5.00 per share or an exercise price of less than $5.00 per share, subject to certain exceptions. Our securities are covered by the penny stock rules, which impose additional sales practice requirements on broker-dealers who sell to persons other than established customers and "accredited investors". The term "accredited investor" refers generally to institutions with assets in excess of $5,000,000 or individuals with a net worth in excess of $1,000,000 or annual income exceeding $200,000 or $300,000 jointly with their spouse. The penny stock rules require a broker-dealer, prior to a transaction in a penny stock not otherwise exempt from the rules, to deliver a standardized risk disclosure document in a form prepared by the SEC which provides information about penny stocks and the nature and level of risks in the penny stock market. The broker-dealer also must provide the customer with current bid and offer quotations for the penny stock, the compensation of the broker-dealer and its salesperson in the transaction and monthly account statements showing the market value of each penny stock held in the customer's account. The bid and offer quotations, and the broker-dealer and salesperson compensation information, must be given to the customer orally or in writing prior to effecting the transaction and must be given to the customer in writing before or with the customer's confirmation. In addition, the penny stock rules require that prior to a transaction in a penny stock not otherwise exempt from these rules, the broker-dealer must make a special written determination that the penny stock is a suitable investment for the purchaser and receive the purchaser's written agreement to the transaction. These disclosure requirements may have the effect of reducing the level of trading activity in the secondary market for the stock that is subject to these penny stock rules. Consequently, these penny stock rules may affect the ability of broker-dealers to trade our securities. We believe that the penny stock rules discourage investor interest in and limit the marketability of our common stock.

The Financial Industry Regulatory Authority, or FINRA, has adopted sales practice requirements which may also limit a stockholder's ability to buy and sell our stock.

In addition to the "penny stock" rules described above, FINRA has adopted rules that require that in recommending an investment to a customer, a broker-dealer must have reasonable grounds for believing that the investment is suitable for that customer. Prior to recommending speculative low priced securities to their non-institutional customers, broker-dealers must make reasonable efforts to obtain information about the customer's financial status, tax status, investment objectives and other information. Under interpretations of these rules, FINRA believes that there is a high probability that speculative low priced securities will not be suitable for at least some customers. FINRA requirements make it more difficult for broker-dealers to recommend that their customers buy our common stock, which may limit your ability to buy and sell our stock and have an adverse effect on the market for our shares.
 

We may be deemed a shell company which could affect liquidity in our common stock
 
Prior to our acquisition of JHE Holdings, LLC, we were engaged in the business of on-line customer support and software development. Due to the downturn in the economy arising out of the debt crisis and increased competition, we had very limited success developing clients to purchase our systems and failed to raise sufficient capital to effectively implementing our business plan. As a result, we examined opportunities to diversify our business including complementary technology businesses and resource based business including oil and gas business opportunities. As a result, we may have been deemed a “shell company.” A shell company is defined as a registrant “that has: (1) no or nominal operations; and (2) either: (i) no or nominal assets; (ii) assets consisting solely of cash and cash equivalents; or (iii) assets consisting of any amount of cash and cash equivalents and nominal other assets.” If we are deemed a shell company there will be (i) additional restrictions on the resale of restricted shares, (ii) additional disclosure required on an acquisition and (iii) increased cost related to disclosure and reporting compliance. On July 25, 2011 we received a comment letter dated June 30, 2011 from the SEC related to our Form 8-K filed on June 21, 2011, requesting that we amend the Form 8-K to provide information required by shell companies. We received subsequent comment letters dated August 12, 2011 and October 6, 2011. Our response to these comment letters is that we do not believe that we are or have ever been a shell company.

If we are deemed a shell company, shareholders holding restricted, non-registered shares will not be able to use the exemptions provided under Rule 144, for twelve months, for the resale of their shares of common stock.

Risks Relating To the Offering

We will have broad discretion as to the use of the net proceeds from this offering, and we may not use the proceeds effectively.
 
Although we plan to use the net proceeds from this offering to fund lease acquisition and drilling in Northwest Kansas and for other general corporate purposes, our management will have broad discretion as to the application of the net proceeds.  Our shareholders may not agree with the manner in which our management chooses to allocate and spend the net proceeds.  Moreover, our management may use some of the net proceeds for corporate purposes that may not increase our market value or profitability.
 
You will experience immediate and substantial dilution in the book value of the shares you purchase in this offering.
 
Investors purchasing shares of our common stock in this offering will pay more for their shares than the amount paid by most existing shareholders who acquired shares prior to this offering.  Based upon the issuance and sale of [●] shares of our common stock at an initial public offering price of $[●] per share, you will incur immediate dilution of approximately $[●]  in the net tangible book value per share if you purchase common stock in this offering. Further dilution may occur in the future, as holders of 10% Convertible Notes issued on February 8, 2012 in the principal amount of $2,750,000, and holders of the 6% Convertible Notes in the principal amount of $1,500,000 issued on September 14, 2011 may convert such convertible notes at $1.50 per share of common stock and the holder a $550,000 convertible note on August 15, 2012 may convert such note at the lesser of $0.55 or at a share value of 75% of the lowest closing share price for the 25 days preceding a conversion.
 
If we are not the subject of securities analyst reports or if any securities analyst downgrades our common stock or our sector, the price of our common stock could be negatively affected.
 
Securities analysts may publish reports about us or our industry containing information about our Company that may affect the trading price of our common stock.  In addition, if a securities or industry analyst downgrades the outlook for our stock or one of our competitors’ stock, the trading price of our common stock may also be negatively affected.

Future sales of our common stock by our existing stockholders may negatively impact the trading price of our common stock.
 
If a substantial number of our existing stockholders decide to sell shares of their common stock in the public market following the completion of this offering, the price at which our common stock trades could decline.  Additionally, the public market’s perception that such sales might occur may also depress the price of our common stock.  Certain existing stockholders have entered into lockup agreements pursuant to which they have agreed not to sell shares of our common stock in the public market for a period of 180 days following the completion of this initial public offering.  Of the [●] shares outstanding upon the completion of this initial public offering, [●] shares will be freely tradeable without restriction and [●] shares will be freely tradeable following the expiration of the 180-day lockup period.
 
 
If we are not able to close a $5,000,000 financing the convertible notes issued on February 8, 2012 will not be extended to September 30, 2014 but instead will be due on February 8, 2013.
 
On February 8, 2012, we issued 10% convertible notes in the aggregate principal amount of $2,750,000, subject to the terms of the Inter-Creditor Agreement. The 10% notes bear interest at the rate of 10% per annum on the unpaid principal balance, which is payable monthly in arrears on the first business day of each calendar month.  The 10% notes are due and payable on February 8, 2013 or at the election of the applicable holder on the earlier of (i) our closing of a financing transaction for aggregate proceeds in excess of $5,000,000, which excess amount shall be applied to the principal balance of the applicable holder’s note (based on the ratio of the principal amount of such holder’s note relative to the aggregate principal amount of all the notes issued on February 8, 2012); (ii) the sale or partial sale of JHE Holdings, LLC; (iii) the sale of all or substantially all of the assets of JHE Holdings, LLC; or (iv) an Event of Default (as defined in the notes issued on February 8, 2012).  The notes are convertible at the option of the holders into shares of our common stock on February 8, 2013 or upon the occurrence of one or more of the triggering events set forth in clauses (i), (ii), and (iii) above, at a conversion price of $1.50 per share. On October 9, 2012 we entered into note extension agreements with the holders of the 10% notes whereby the holders agreed to extend the maturity date of the notes to September 30, 2014 on the closing of a $5,000,000 financing within ninety days of execution of the note extension agreements, or as extended by additional thirty day periods, which are to be granted at the sole discretion of the holders of the notes. As an incentive to enter into the note extension agreements, the holders of the notes were issued an aggregate amount of 250,000 shares of our common stock on execution of the note extension agreement and they will receive an additional aggregate amount of 250,000 shares of our common stock on closing of the $5,000,000 financing. Pursuant to the note extension agreements accrued interest under the notes from May 1, 2012 until the closing of the financing, shall be paid on closing of the financing and subsequent to the financing interest shall be paid on a monthly basis.  Should the financing not occur within the ninety day period or within an extension period, then the original terms of the notes shall remain in effect.

The foregoing description of the note extension agreements is qualified in its entirety by reference to the copy of the form of note extension agreement included as Exhibit 10.29 to the Form S-1 filed with the SEC on October 10, 2012.
 
 
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS
 
This prospectus contains “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995.  Such forward-looking statements concern our anticipated results and developments in our operations in future periods, planned exploration and development of its properties, plans related to its business and other matters that may occur in the future.  These statements relate to analyses and other information that are based on forecasts of future results, estimates of amounts not yet determinable and assumptions of our management.
 
Any statements that express or involve discussions with respect to predictions, expectations, beliefs, plans, projections, objectives, assumptions or future events or performance (often, but not always, using words or phrases such as “expects” or “does not expect”, “is expected”, “anticipates” or “does not anticipate”, “plans”, “estimates” or “intends”, or stating that certain actions, events or results “may”, “could”, “would”, “might” or “will” be taken, occur or be achieved) are not statements of historical fact and may be forward-looking statements.  Forward-looking statements are subject to a variety of known and unknown risks, uncertainties and other factors which could cause actual events or results to differ from those expressed or implied by the forward-looking statements, including, without limitation:
 
risks related to the competition from large number of established and well-financed entities that are actively involved in the oil and gas development business;
risks related to drilling, completion and facilities costs;
risks related to abandonment and reclamation costs;
risks related to the performance and characteristics of our oil and gas properties;
risks related to expected royalty rates, operating and general administrative costs, costs of services and other costs and expenses;
risks related to our oil and gas production levels;
risks related to fluctuations in the price of oil and gas, interest and exchange rates;
risks related to the oil and gas industry, such as risks in developing and producing crude oil and natural gas and market demand;
risks related to actions taken by governmental authorities, including increases in taxes and changes in government regulations and incentive programs;
risks related to geological, technical, drilling and processing problems;
risks and uncertainties involving geology of oil and gas deposits;
risks related to our ability to locate satisfactory properties for acquisition or participation;
risks related to shut-ins of connected wells resulting from extreme weather conditions;
risks related to hazards such as fire, explosion, blowouts, cratering and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury;
risks related to encountering unexpected formations or pressures, premature decline of reservoirs and the invasion of water into producing formations;
risks related to the possibility that government policies or laws, including laws and regulations related to the environment, may change or governmental approvals may be delayed or withheld;
risks related to competition for and/or inability to retain drilling rigs and other services;
risks related to competition for, among other things, capital, acquisition of reserves, undeveloped land and skilled personnel;
risks related to our history of operating losses, our limited financial resources and our needs for additional financing;
risks related to the integration of our new management and implementation of our expanded business strategy in the oil and gas development business;
other risks related to the thinly traded market for our securities; and
risks related to holding non-operated interests in properties operated by third-party operators, including our lack of control on the schedule of development, budgeting and production decisions and our reliance on third-party operators.

This list is not exhaustive of the factors that may affect our forward-looking statements.  Some of the important risks and uncertainties that could affect forward-looking statements are described further under the sections titled “Risk Factors”, “Business” and “Management’s Discussion and Analysis of Financial Condition and Operating Results” of this prospectus.  Should one or more of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results may vary materially from those anticipated, believed, estimated or expected.  We caution readers not to place undue reliance on any such forward-looking statements, which speak only as of the date made.  We disclaim any obligation subsequently to revise any forward-looking statements to reflect events or circumstances after the date of such statements or to reflect the occurrence of anticipated or unanticipated events, except as required by law.
 
Our financial statements are stated in United States dollars and are prepared in accordance with United States generally accepted accounting principles.

In this prospectus, unless otherwise specified, all dollar amounts are expressed in United States dollars and all references to "common stock" refer to the common shares in our capital stock.

We qualify all the forward-looking statements contained in this prospectus by the foregoing cautionary statements.
 
 
USE OF PROCEEDS
 
We estimate that our net proceeds, after deducting the estimated expenses related to this offering, including commissions and accountable and non-accountable expenses of the Placement Agent, will be approximately $6,291,510 .

We intend to use the estimated net proceeds as follows:

   
Approximate Amount
   
Percent of Net Proceeds
 
To acquire properties in Western Kansas or other areas
 
$
4,190,000
     
65
%
To fund drilling programs
 
$
2,000,000
     
31
%
To fund working capital needs and other general corporate purposes
 
$
125,000
     
2
%
To retire certain accounts payable, accrued expenses and other short-term liabilities
 
$
125,000
     
2
%

The foregoing represents our current intentions based upon our current plans and business condition.  Management will have broad discretion in the application of our net proceeds from this offering, and the occurrence of unforeseen events or changes in business conditions could result in the application of our net proceeds from this offering in a manner other than as described in this prospectus.  Pending application of our net proceeds, we intend to invest the net proceeds in short-term, interest- bearing, investment-grade securities.
 
PRICE RANGE OF COMMON STOCK
 
We are traded on the OTCBB under the ticker symbol “CRCL.”  We had previously been trading under the symbol “DTLV” but changed its ticker symbol to “CRCL” effective July 1, 2011.
 
PERIOD
 
LOW ($)
   
HIGH ($)
 
First Quarter of Fiscal Year 2011 (ended July 31, 2010)
   
0.005
     
0.005
 
Second Quarter of Fiscal Year 2011  (ended October 31, 2010)
   
0.005
     
0.1
 
Third Quarter of Fiscal Year 2011  (ended January 31, 2011)
   
0.1
     
0.13
 
Fourth Quarter of Fiscal Year 2011 (ended April 30, 2011)
   
0.13
     
0.50
 
First Quarter of Fiscal Year 2012 (ended July 31, 2011)
   
0.5
     
2.25
 
Second Quarter of Fiscal Year 2012 (ended October 31, 2011)
   
1.87
     
2.00
 
Third Quarter of Fiscal Rear 2012 (ended January 31, 2012)
   
1.87
     
2.15
 
Fourth Quarter of Fiscal Year 2012 (ended April 30, 2012)
   
2.00
     
2.75
 
First Quarter of Fiscal Year 2013 (ended July 31, 2012)
   
0.45
     
2.38
 
Second Quarter of Fiscal Year 2012 (ended October 31, 2012)
   
0.16
     
0.58
 

The closing price per share for our common stock on January 11, 2013 as reported by the OTCBB was $0.35 .

 
The following table sets forth our: (i) cash and cash equivalents; (ii) restricted cash and marketable securities; (iii) total assets; (iv) total liabilities; (v) components of stockholders’ equity; (vi) total capitalization; and (vi) outstanding shares of common stock as of October 31, 2012, as follows:
 
·  
on an actual basis; and
 
·  
on a pro forma as adjusted basis to reflect the sale by us of [●] shares of common stock in this offering, based on an assumed initial public offering price of $[●] per share, which is the midpoint of the range shown on the cover of this prospectus, and after deduction estimated placement agent fees, commissions and advisory fees and estimated offering expenses payable by us.
 
 
You should read this table together with the sections of this prospectus entitled “Use of Proceeds”, as well as our consolidated financial statements and related notes and the other financial information appearing elsewhere in this prospectus.

   
As of October 31, 2012
 
   
Actual
   
Pro Forma as Adjusted
 
Cash and cash equivalents
 
$
66,988
   
$
[ - ]
 
                 
Total Assets
 
$
4,689,621
    $
 [·]
 
                 
Convertible notes payable, net of discount
 
$
3,742,498
    $
 [·]
 
                 
Stockholders’ Equity:
               
Common stock:$0.001 par value, 41,754,571 shares issued and outstanding (actual), and [●] as adjusted
   
 41,755
         
Additional paid-in capital
   
18,817,298
     
[●]
 
Accumulated deficit
   
(19,054,400
)
   
([●]
Total Stockholders' Equity (Deficit)
   
(195,347)
     
[●]
 
                 
Total Capitalization
 
$
3,547,151
     
[●]
 
 

The outstanding share information set forth above as of October 31, 2012, excludes:

·
Up to 3,000,000 shares of common stock reserved for future issuance under our 2011 Stock Option Plan ;

·
250,000 shares of common stock underlying outstanding warrants as of August 16, 2012;

·
450,000 shares of common stock reserved for issuance to our independent directors;

·
10,437,000 shares of common stock reserved for issuance to our employees and officers;

·
1,833,333 shares of common stock reserved for issuance upon conversion of 10% convertible notes we issued on February 8, 2012;

·
250,000 shares of common stock reserved for issuance to the holders of 10% convertible notes due February 8, 2013 on closing on closing of a $5,000,000 financing;

·
1,000,000 shares of common stock reserved for issuance upon conversion of the 6% convertible notes due September 14, 2014;

·
1,145,833 shares of common stock reserved for issuance upon conversion of a Promissory Note issued on August 15, 2012;

·
325,000 shares of common stock issued to Big Sky Management Ltd. for payment of consulting services; and

·
225,000 shares of common stock issued to Wevco Production Inc. for settlement of issues arising from a leasehold purchase agreement, as amended.

 
DILUTION
 
If you invest in our common stock, your interest will be diluted to the extent of the difference between the public offering price per share of our common stock and the as adjusted net tangible book value per share of our common stock immediately after this offering. Net tangible book value per share represents the amount of our total tangible assets less total liabilities, divided by the number of shares of common stock outstanding at October 31, 2012.
 
Our historical net tangible book value at October 31, 2012 was $(●), or  $(●) per share. After giving effect to the sale of our common stock in this offering at an assumed public offering price of $[·] per share, which is the mid-point of the offering range indicated on the cover page of this prospectus and after deducting estimated placement agent fees and commissions and estimated offering expenses payable by us, our adjusted net tangible book value at October 31, 2012 would have been $[·] million or $[·] per share. This represents an immediate increase in net tangible book value per share of $[·] to existing stockholders and dilution in net tangible book value per share of $[·] to new investors who purchase shares in the offering. The following table illustrates this per share dilution to new investors:

Assumed public offering price per share
 
[●]
 
Historical net tangible book value per share at July 31, 2012
 
(●)
 
Increase in net tangible book value per share attributable to new investors
 
[●]
 
Adjusted net tangible book value per share
 
[●]
 
Dilution per share to new investors
 
[●]
 
 
The following table sets forth, on the as adjusted basis described above, at October 31, 2012, the difference between the number of shares of common stock purchased from us, the total consideration paid, and the average price per share paid by the existing stockholders and by investors purchasing shares in this offering, before deducting estimated placement agent fees and commissions and estimated offering expenses.

   
Shares Purchased
   
Total Consideration
       
   
Number
   
Percent
   
Amount
   
Percent
   
Average Price Per Share
 
Existing stockholders
   
[●]
     
[●]
%
 
$
[●]
     
[●]
%
 
$
[●]
 
New investors                               
   
[●]
     
[●]
%
   
[●]
     
[●]
%
   
[●]
 
     Total                               
   
[●]
     
100
%
 
$
[●]
     
100
%
 
$
[●]
 
 
The discussions and tables above are based on the number of shares of common stock outstanding at October 31, 2012. The outstanding share information set forth above excludes:

·
Up to 3,000,000 shares of common stock reserved for future issuance under our 2011 Stock Option Plan ;

·
250,000 shares of common stock underlying outstanding warrants as of August 16, 2012;

·
450,000 shares of common stock reserved for issuance to our independent directors;

·
10,437,000 shares of common stock reserved for issuance to our employees and officers;

·
1,833,333 shares of common stock reserved for issuance upon conversion of 10% convertible notes we issued on February 8, 2012;

·
250,000 shares of common stock reserved for issuance to the holders of 10% convertible notes due February 8, 2013 on closing on closing of a $5,000,000 financing;

·
1,000,000 shares of common stock reserved for issuance upon conversion of the 6% convertible notes due September 14, 2014;

·
1,145,843 shares of common stock reserved for issuance upon conversion of the promissory note we issued on August 15, 2012;

·
325,000 shares of common stock issued to Big Sky Management Ltd. for payment of consulting services; and

·
225,000 shares of common stock issued to Wevco Production Inc. for settlement of issues arising from a leasehold purchase agreement, as amended.

 
DIVIDEND POLICY
 
We have not paid any cash dividends on our common stock and have no present intention of paying any dividends on the shares of our common stock.  Our future dividend policy will be determined from time to time by our Board.
 
HOLDERS OF OUR COMMON STOCK
 
On January 11, 2013 the shareholders’ list of our common stock had 66 registered shareholders and 42,304,571 shares outstanding.
 
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND OPERATING RESULTS
 
You should read the following discussion and analysis of our financial condition and results of operations together with our financial statements and related notes appearing elsewhere in this prospectus.  This discussion and analysis contains forward-looking statements that involve risks, uncertainties and assumptions.  Our actual results may differ materially from those anticipated in these forward-looking statements as a result of many factors, including, but not limited to, those set forth under “Risk Factors” and elsewhere in this prospectus.
 
Our consolidated financial statements are stated in United States dollars and are prepared in accordance with United States generally accepted accounting principles.

Critical Accounting Policies and Estimates

The discussion and analysis of our financial condition and results of operations are based upon our consolidated financial statements, which have been prepared in accordance with GAAP. The preparation of our consolidated financial statements requires us to make estimates and assumptions that affect our reported results of operations and the amount of reported assets, liabilities and proved oil and gas reserves. Some accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. Actual results may differ from the estimates and assumptions used in the preparation of our consolidated financial statements. Described below are the most significant policies we apply in preparing our consolidated financial statements, some of which are subject to alternative treatments under GAAP. We also describe the most significant estimates and assumptions we make in applying these policies. See Note 1 to our consolidated financial statements.

Segment reporting is not applicable to us as we have a single, company-wide management team that administers all properties as a whole rather than by discrete operating segments. We track only basic operational data by area. We do not maintain complete separate financial statement information by area. We measure financial performance as a single enterprise and not on an area-by-area basis. We use the successful efforts method of accounting for our oil and gas activities.

Successful Efforts Method of Accounting

We follow the successful efforts method of accounting for our oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties and to drill and equip development wells and related asset retirement costs are capitalized. Costs to drill exploratory wells are capitalized pending determination of whether the wells have proved reserves. If we determine that the wells do not have proved reserves, the costs are charged to expense. There were no exploratory wells capitalized pending determination of whether the wells have proved reserves at April 30, 2012 or 2011. Geological and geophysical costs, including seismic studies and costs of carrying and retaining unproved properties are charged to expense as incurred. We capitalize interest on expenditures for significant exploration and development projects that last more than six months while activities are in progress to bring the assets to their intended use. Through April 30, 2012, we have capitalized no interest costs because our exploration and development projects generally last less than six months. Costs incurred to maintain wells and related equipment are charged to expense as incurred.

Proved Reserves

For the year ended April 30, 2012 we engaged LaRoche Petroleum Consultants, Ltd., independent petroleum engineers, to prepare independent estimates of the extent and value of 100% of our reported proved reserves, in accordance with guidelines established by the SEC, including the Final Rule.
 

Estimates of proved oil and gas reserves directly impact financial accounting estimates including depletion, depreciation and amortization expense, evaluation of impairment of properties and the calculation of plugging and abandonment liabilities.  Proved oil and gas reserves are those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward, from known reservoirs, and under existing economic conditions, operating methods and government regulations. The process of estimating quantities of proved reserves is very complex, requiring significant subjective decisions in the evaluation of all geological, engineering and economic data for each reservoir. The data for any reservoir may change substantially over time due to results from operational activity. Proved reserve volumes at April 30, 2012, were estimated based on the average of the closing price on the first day of each month for the 12-month period prior to April 30, 2012, for oil, and natural gas in accordance with the Final Rule. Changes in commodity prices and operations costs may increase or decrease estimates of proved oil and natural gas reserves. Depletion expense for our oil and gas properties is determined using our estimates of proved oil and gas reserves.

Share-based Compensation

We measure and record compensation expense for all share-based payment awards to employees and directors based on estimated grant-date fair values.  Compensation costs for share-based awards are recognized over the requisite service period based on the grant-date fair value. We measure grant-date fair value of share awards using the closing stock price on the date of the award.  For stock option awards, we estimate fair value using the Black-Scholes method.  Inputs to that estimate subject to our judgment include volatility and the expected life of the awards.  For volatility, we use the historic volatility for public companies comparable to our company in size and operations, measured over a period similar to the expected lives of our grants.  Expected lives are based on our judgment of the amount of time that the award will be outstanding prior to its exercise.  We do not include estimated forfeiture rates because we do not expect the persons subject to option awards to leave the company prior to the awards vesting.  Actual outcomes can differ significantly from our estimates.

Carrying Value of Oil and Gas Properties

In determining impairments, we assess undiscounted cash flow for a field relative to its carrying value. If a field's undiscounted cash flow is less than its carrying value, the field will be impaired. If a field's undiscounted cash flow is less than its fair market value but exceeds its carrying value, the field may be impaired as a result of lower commodity prices. Fair market value is generally considered to be the price that a willing buyer would pay and a willing seller would accept for a property that has been exposed to the market for a reasonable period, with neither party being under compulsion to buy or sell, and both having a reasonable knowledge of the relevant facts. Estimates of fair market value are based on our knowledge of current trading values of petroleum properties correlated with projected producing rates and the quality of reserves. Our calculation of the fair market value for each field area used our internal interpretation of proved, probable and possible reserves and consider various price and cost scenarios to recovery these reserves. The key assumptions we used in our evaluation were the NYMEX futures price strip as of the valuation date and the current cost to produce the properties. The net present value for each reserve category was then risked. This total risked net present value calculation was compared to generally known trading values on a reserve and production basis. In addition, we considered most recent cash flow multiples and future project cash flows to estimate a reasonable fair market value for each property.

As in all aspects of oil and gas evaluation, there are uncertainties inherent in the interpretation of engineering and geoscience data; therefore, our conclusions necessarily represent only informed professional judgment. Our estimation of fair market value has been influenced by our understanding of the technological, economic, political, and other factors that may affect the value of the properties.

Estimates of reserves may increase or decrease as a result of market conditions, future operations, changes in regulations, or actual reservoir performance. In addition to certain economic assumptions, our estimates are based on other assumptions including, but not limited to, that the properties will be developed consistent with current development plans, that the properties will be operated in a prudent manner, that no governmental regulations or controls will be put in place that would impact the ability of the interest owner to recover the reserves, and that our projections of future production will prove consistent with actual performance. If the reserves are recovered, the revenues therefrom and the costs related thereto could be more or less than the estimated amounts. Because of governmental policies and uncertainties of supply and demand, the sales rates, prices received for the reserves, and costs incurred in recovering such reserves may vary from assumptions used in our evaluation.
 

Activities to Date

On June 16, 2011, we completed the Acquisition of JHE Holdings, LLC in accordance with terms of a purchase agreement.  Pursuant to the purchase agreement, we acquired all of the membership interests in JHE Holdings, LLC and accordingly, JHE Holdings, LLC became our wholly-owned subsidiary.  JHE Holdings, LLC owns royalty, non-operated working interests and mineral interests in certain oil and gas properties in Texas. The properties that we hold through our subsidiary JHE Holdings, LLC include producing wells in the TXL Extension, Crane County, TX (1.00% working interest and 0.75% revenue interest in two wells); Bullard Prospect, Scurry County, TX (1.25% – 2.50% working interest and 0.94% – 2.08% revenue interest in nine wells); Nursery Prospect, Victoria County, TX (2.75% working interest and 2.00% – 2.10% revenue interest in two wells); Pearsall Prospect, Dimmit and Zavala Counties, TX (0.24% - 5.00% working interest and 0.17% – 3.75% revenue interest in 25 wells); Madison Woodbine, Grimes and Madison Counties, TX (0.00% - 2.90% working interest and 0.0190% – 2.90% revenue interest in seven wells); Giddings Field, Fayette and Lee Counties, TX (0.00% - 3.00% working interest and 0.76% – 2.28% revenue interest in six wells).

See Section entitled “Business” below for more information on our activities.
 
Results of Operations for the Three and Six Months Ended October 31, 2012

The financial information with respect to the three and six months ended October 31, 2012 and 2011, as discussed below is unaudited. In the opinion of management, such information contains all adjustments (consisting primarily of normal recurring accruals) necessary for a fair presentation of the results for such periods.  The results of operations for interim periods are not necessarily indicative of the results of operations for the full fiscal years. The table below presents the results of operations for the three and six months ended October 31, 2012.
 
   
Three Months Ended
   
Six Months Ended
 
   
October 31,
2012
   
October 31,
2011
   
October 31,
2012
   
October 31,
2011
 
   
(unaudited)
   
(unaudited)
   
(unaudited)
   
(unaudited)
 
Consolidated Statement of Operations:
                       
Revenues
 
$
211,454
   
$
293,677
   
$
362,058
   
$
509,971
 
Lease operating, production and other
   
28,777
     
40,003
     
53,887
     
66,742
 
General and administrative
   
1,333,693
     
997,136
     
2,760,479
     
2,476,881
 
Depreciation  depletion and amortization
   
133,761
     
191,738
     
216,226
     
270,164
 
Impairment of oil and gas properties
   
3,566,497
     
-
     
3,566,497
     
3,397,693
 
Exploration costs
   
55,072
     
-
     
80,579
     
2
 
Loss from operations
   
(4,906,346
)
   
(935,200
)
   
(6,315,610
)
   
(5,701,511
)
                                 
Net loss
   
(5,875,213
)
   
(1,365,448
)
   
(7,805,917
)
   
(6,461,759
)
 

The following table sets forth summary information regarding oil gas production, average sales prices and average production costs for the three and six months ended October 31, 2012. We determined the Boe using the ratio of six Mcf of natural gas to one Boe. The ratios of six Mcf of natural gas to one Boe does not assume price equivalency and, given price differentials, the price for a Boe for natural gas may differ significantly from the price for a barrel of oil.
 
   
Three Months Ended
   
Six Months Ended
 
   
October 31,
2012
   
October 31,
2011
   
October 31,
2012
   
October 31,
2011
 
Revenues:
                       
Oil
 
$
195,997
   
$
174,336
   
$
343,398
   
$
247,552
 
Gas
   
15,457
     
119,341
     
18,660
     
262,419
 
Total oil and gas sales
 
$
211,454
   
$
293,677
   
$
362,058
   
$
509,971
 
Production:                                
Oil (Bbls)
   
2,132
     
2,084
     
3,710
     
4,459
 
Gas (Mcf)
   
3,067
     
24,304
     
4,542
     
52,121
 
Total (Boe)
   
2,643
     
6,134
     
4,467
     
13,146
 
Total (Boe/d)
   
29
     
67
     
24
     
71
 
                                 
Average Prices
                               
Oil (per bbls)
 
$
91.93
   
$
83.67
   
$
92.56
   
$
55.52
 
Gas (Per Mcf)
   
1.99
     
4.91
     
2.17
     
5.03
 
Total (Per Boe)
 
$
80.01
   
$
47.88
   
$
81.05
   
$
38.79
 
                                 
Production Costs (Per Boe)
 
$
10.89
   
$
6.52
   
$
12.06
   
$
5.04
 

Revenue and Operating Trends
 
For the three and six months ended October 31, 2012, we did not generate sufficient revenues to cover our operating expenses. We do not anticipate generating sufficient revenue from operations to cover our operating expenses in the near term.
 
Company Overview for the three and six months ended October 31, 2012
 
Our net loss for the three and six months ended October 31, 2012 was $5,875,213 and $7,805,917, respectively.  From our inception through October 31, 2012, we have received nominal revenues from our oil and natural gas activities, while incurring substantial acquisition and impairment costs and overhead expenses which have resulted in an accumulated deficit through October 31, 2012 of $19,054,400. We anticipate that we will incur net losses through fiscal 2013 and beyond until we can significantly increase production and revenue.
 
Comparison of Results of Operations for the three months ended October 31, 2012 and 2011
 
Oil and gas sales. Oil and gas sales decreased $82,223, or 28%, for the three months ended October 31, 2012, to $211,454 from $293,677 for the three months ended October 31, 2011. The $82,223 decrease in oil, NGL, and gas sales was primarily attributable to a decrease in production volumes, partially offset by increases in the average price per Boe.  Production volumes decreased primarily due to the sales of certain interests in properties held by JHE Holdings, LLC that were operated by Encana (the “Encana Properties”) and the average price per Boe increased due to an increase in oil production as a percentage of total oil, NGL, and gas production.  
 
Oil and gas production. Production for the three months ended October 31, 2012 totaled 2,643 Boe (29Boe/d), compared to 6,134Boe (67Boe/d) in the prior year period, a decrease of 57%.  The decrease in production in the 2012 period is the result primarily of the sale of the Encana properties.  Subject to commodity prices, which could impact drilling activity, we expect production to increase during the remainder of the fiscal year ending April 30, 2013.

Lease operating expenses. Our lease operating expenses decreased $10,836, or 38% to $18,011 for the three months ended October 31, 2012, from $28,847 for the three months ended October 31, 2011. The $6.81 per Boe LOE in 2012 as compared to $4.70 per Boe in the 2011 period was primarily attributable to decreases in production as described elsewhere herein resulting in a decrease in expense and an increase in expense on a Boe basis. 
 
 
Severance and production taxes. Our severance and production taxes decreased $390, or 3% to $10,766 for the three months ended October 31, 2012, from $11,156 for the three months ended October 31, 2011. The decrease in severance and production taxes was primarily a function of both the decrease in overall sales and an increase in oil sales as a percentage of total oil and gas sales, as oil sales are taxed at a lower rate.  Severance and production taxes were approximately 5.0% and 3.8% of oil and gas sales for the respective periods.
 
General and administrative. Our general and administrative expenses (“G&A”) increased $336,557or 33.8%, to $1,333,693 for the three months ended October 31, 2012, from $997,136 for the three months ended October 31, 2011.  The increase in G&A was primarily due to lower share-based compensation partially offset by higher salaries and benefits resulting from increased staffing.  For the remainder of 2012, we expect G&A to remain reasonably stable.  

Depletion, depreciation, and amortization. Our depletion, depreciation, and amortization expense (“DD&A”) decreased $57,977 or 30%, to $133,761 for the three months ended October 31, 2012, from $191,738 for the three months ended October 31, 2011.  Our DD&A per Boe for the three months ended October 31, 2012 was $50.61 per Boe as compared to $31.26 per Boe in the 2011 period. The decrease in DD&A expense over the prior year period was primarily due to lower production in 2012.  
 
Impairment of Oil and Gas Properties.  Impairment charges incurred during the three months ended October 31, 2012 resulted from the loss of $17,500 of our deposit on the Greene Acquisition, and the loss of $3,548,997 of our deposits on the Wevco Production Inc. acquisition.
 
Exploration costs.  Our exploration costs increased $55,072 or 100% to $55,072 for the three months ended October 31, 2012, from $nil for the three months ended October 31, 2011. The increase in exploration costs over the prior year period was attributable to delay rentals.
 
Interest expense, net.  Our interest expense, net, increased $93,140, or 22%, to $523,388 for the three months ended October 31, 2012, from $430,248 for the three months ended October 31, 2011. This increase was primarily the result of a higher average debt level from the assumption of a note payable related to the acquisition of JHE and the issuance of convertible notes payable during the 2012 period coupled with one time interest charges related to the conversion of convertible notes payable and the origination of a convertible note payable. We expect our interest expense to remain higher for the remainder of the fiscal year than the prior year period as a result of increased borrowings during 2012.
 
Comparison of Results of Operations for the six months ended October 31, 2012 and 2011
 
Oil and gas sales. Oil and gas sales decreased $147,913, or 29%, for the six months ended October 31, 2012, to $362,058 from $509,971 for the six months ended October 31, 2011. The $147,913decrease in oil and gas sales was primarily attributable to a decrease in production volumes, partially offset by increases in the average price per Boe.  Production volumes decreased primarily due to the sales of the Encana Properties and the average price per Boe increased due to an increase in oil production as a percentage of total oil and gas production.  
 
Oil and gas production. Production for the six months ended October 31, 2012 totaled 4,467Boe (24Boe/d), compared to 13,146Boe (71Boe/d) in the prior year period, a decrease of 66%.  The decrease in production in the 2012 period is the result primarily of the sale of the Encana properties offset slightly by increased production volumes in October 2012.  Subject to commodity prices, which could impact drilling activity, we expect continued production to increases during the remainder of the fiscal year ending April 30, 2013.

Lease operating expenses. Our lease operating expenses decreased $2,005, or 5% to $35,785 for the six months ended October 31, 2012, from $37,790 for the six months ended October 31, 2011. The $8.01 per Boe LOE in 2012 as compared to $2.87 per Boe in the 2011 period was primarily was primarily due reduced production volumes as described elsewhere herein.

Severance and production taxes. Our severance and production taxes decreased $10,850, or 37% to $18,102 for the six months ended October 31, 2012, from $28,952 for the six months ended October 31, 2011. The decrease in severance and production taxes was primarily a function of both the decrease in overall sales and an increase in oil sales as a percentage of total oil, NGL, and gas sales, as oil sales are taxed at a lower rate.  Severance and production taxes were approximately 5.0% and 5.7% of oil, NGL and gas sales for the respective periods.  
 
General and administrative. Our general and administrative expenses (“G&A”) increased $283,598or 11%, to $2,760,479 for the six months ended October 31, 2012, from $2,476,881 for the six months ended October 31, 2011.  The increase in G&A was primarily due to lower share-based compensation partially offset by higher salaries and benefits resulting from increased staffing.  For the remainder of 2012, we expect G&A to remain reasonably stable.  
 

Depletion, depreciation, and amortization. Our depletion, depreciation, and amortization expense (“DD&A”) decreased $53,938 or 20%, to $216,226 for the six months ended October 31, 2012, from $270,164 for the six months ended October 31, 2011. Our DD&A per Boe for the six months ended October 31, 2012 was $48.41 per Boe as compared to $20.55 per Boe in the 2011 period. The increase in Boe DD&A over the prior year period was primarily due to lower production in  2012.   
 
Impairment of Oil and Gas Properties. Impairment charges incurred during the six months ended October 31, 2012 resulted from the loss of $17,500 of our deposit on the Greene Acquisition, and the loss of $3,548,997 of our deposits on the Wevco Production Inc. acquisition.  Impairment charges incurred during the six months ended October 31, 2011 resulted from our acquisition of JHE Holdings, LLC in which the consideration we paid for the net assets of JHE Holdings, LLC exceeded the fair value of the net assets acquired.  Accordingly, we recorded an impairment charge on the acquisition date.
 
Exploration costs.  Our exploration costs increased $80,579 or 100% to $80,579 for the six months ended October 31, 2012, from $nil for the six months ended October 31, 2011.   The increase in exploration costs over the prior year period was attributable to delay rentals.
 
Interest expense, net.  Our interest expense, net, increased $204,649, or 27%, to $964,897 for the six months ended October 31, 2012, from $760,248 for the six months ended October 31, 2011. This increase was primarily the result of a higher average debt level from the assumption of a note payable related to the acquisition of JHE Holdings, LLC and convertible notes payable during the 2012 period coupled with one time charges to interest expense related to the conversion of convertible notes payable and the origination of a convertible note payable.

 Results of Operations for the fiscal year ended April 30, 2012 compared to the fiscal year April 30, 2011

The following table sets forth summary information regarding oil and gas revenues, production, average product prices and average production costs and expenses for the fiscal year ended April 30, 2012.  We had no oil and gas operations prior to the fiscal year beginning May 1, 2011. We determined the Boe using the ratio of six Mcf of natural gas to one Boe. The ratios of six Mcf of natural gas to one Boe do not assume price equivalency and, given price differentials, the price for a Boe for natural gas or natural gas liquids (“NGLs”) may differ significantly from the price for a barrel of oil.
 
   
Year Ended April 30, 2012
 
 Revenues
     
 Oil
 
$
758,798
 
 Gas
   
183,352
 
 Total oil and gas sales
 
$
942,150
 
 Production
       
 Oil (Bbls)
   
9,792
 
 Gas (Mcf)
   
51,036
 
 Total (Boe)
   
18,298
 
 Total (Boe/d)
   
50
 
 Average prices
       
 Oil (per Bbl)
 
$
77.49
 
 Gas (per Mcf)
   
3.59
 
 Total (per Boe)
 
$
51.49
 
 Costs and expenses (per Boe)
       
 Lease operating (1)
 
$
4.41
 
 Severance and production taxes
   
2.75
 
 Exploration
   
5.04
 
 Impairment
   
211.01
 
 General and administrative
   
316.79
 
 Depletion, depreciation, and amortization
   
31.48
 
 
(1)            Includes ad valorem taxes.

Oil and Gas Sales

Oil and gas sales were $942,150 for the fiscal year ended April 30, 2012.  There were no oil and gas sales in the fiscal year ended April 30, 2011.  The increase in sales was attributable to our acquisition of JHE Holdings, LLC and certain oil and gas properties within the Redfish 56 Prospect in Glasscock County, Texas (collectively the oil and gas assets of JHE Holdings, LLC and Redfish 56 Prospect are known as the “Texas Properties”).  In the fiscal year ended April 30, 2012, the average price we received for our production was $51.49 per Boe.  We believe that revenues will increase during the fiscal year ending April 30, 2013 as we implement our operating and drilling plan.
 

Net Loss

Net loss for the fiscal year ended April 30, 2012 was $11,078,248, or $0.34 per basic and diluted share, compared to a net loss of $31,718, or $0.00 per basic and diluted share for the fiscal year ended April 30, 2011. Net loss per basic and diluted share increased in the fiscal year ended April 30, 2012 over the fiscal year ended April 30, 2011 primarily due to higher total general and administrative expenses and impairment related to the acquisition of the Texas Properties. We believe that we will continue to incur net losses during the fiscal year ending April 30, 2013 although management believes they will decrease as we implement our operating and drilling plan.

Oil and Gas Production

Production for the fiscal year ended April 30, 2012 totaled 18,298 Boe (50 Boe/d).  There was no production in the fiscal year ended April 30, 2011.  Production for the fiscal year ended April 30, 2012 was 54% oil and 46% natural gas.  The increase in production in the fiscal year ended April 30, 2012 is the result of the acquisition of the Texas Properties.  We believe that production will increase during the fiscal year ending April 30, 2013 as we begin to implement our operating and drilling plan.
 
Lease Operating Expense
 
Our lease operating expenses (“LOE”) were 80,723 for the fiscal year ended April 30, 2012. The increase in LOE for the fiscal year ended April 30, 2012 was attributable to the acquisition of the Texas Properties.
 
The following table summarizes LOE per Boe.
 
   
Year Ended
April 30, 2012
 
Non-op LOE
 
$
3.59
 
Ad valorem taxes
   
0.83
 
Total
 
$
4.42
 

Severance and Production Taxes

Our severance and production taxes for the fiscal year ended April 30, 2012 were $50,334 or 5.3% of revenues. There were no severance or production taxes for the fiscal year ended April 30, 2011. The increase in severance and production taxes was due to the acquisition of the Texas Properties.  We believe that production and severance taxes will increase during the fiscal year ending April 30, 2013 as sales increase as a result of the implementation of our operating and drilling plan.

We recorded $92,247 of exploration expense for the fiscal year ended April 30, 2012 and zero for the fiscal year ended April 30, 2011. Exploration expense for the fiscal year ended April 30, 2012 was primarily related to geological and geophysical services incurred for the acquisition of leases in Kansas.  We believe that exploration expenses will increase during the fiscal year ending April 30, 2013 as we implement our operating and drilling plan.

Impairment

We review our long-lived assets, including proved and unproved oil and gas properties accounted for under the successful efforts method of accounting. For the fiscal year ended April 30, 2012, our total impairment expense was $3,861,083. Of this amount, $3,397,693 was related to the acquisition of JHE Holdings, LLC and based on the fair value of assets acquired. The remaining $463,390 relates to the acquisition of certain oil and gas properties within the Redfish 56 Prospect in Glasscock County, Texas and was a result of the evaluation of carrying value of oil and gas properties at year-end.  We do not believe that our assets will be subject to further impairment during the fiscal year ending April 30, 2013 due to the expected future increase in both oil and gas prices.

General and Administrative Expenses

Our general and administrative expenses (“G&A”) increased to $5,796,640 in the fiscal year ended April 30, 2012 from $31,718 in the fiscal year ended April 30, 2011.  The increase in G&A is due to the hiring of a Chief Executive Officer and Chief Financial Officer whose compensation includes share-based compensation of $4,099,558 and professional fees of $1,010,180 incurred related to acquisitions and SEC reporting support.  We expect G&A expenses to continue to rise during the fiscal year ending April 30, 2013 as we incur costs to support our operating and drilling plan and share-based compensation continues to be a significant component of G&A expenses.
 

The following table summarizes.
 
   
Year Ended April 30,
 
   
2012
   
2011
 
 Share-based compensation
 
$
4,099,558
   
$
-
 
 Professional fees
   
1,018,357
     
31,718
 
 Salaries and benefits
   
377,348
     
-
 
 Other
   
301,377
     
-
 
 Total
 
$
5,796,640
   
$
31,718
 

Depletion, Depreciation and Amortization Expense

Our depletion, depreciation and amortization expense (DD&A) was $575,990 in the fiscal year ended April 30, 2012 and zero in the fiscal year ended April 30, 2011. The increase in DD&A was attributable to the acquisition of the Texas Properties.  We expect DD&A to increase during the fiscal year ending April 30, 2013 as we implement our operating and drilling plan and our asset base increases.

Interest Expense, net

Our interest expense, net, was $1,693,084 for the fiscal year ended April 30, 2012 and zero for the fiscal year ended April 30, 2011. This increase was the result of higher average notes payable balances outstanding. The weighted average interest rate applicable to our outstanding borrowings during 2012 was 27.4%.  A note payable in the amount of $7,500,000 was made by us for the purchase of JHE Holdings, LLC to the Edsels, the former owners of JHE Holdings, LLC.  Upon closing of the transaction on June 16, 2011 and effective June 1, 2011, the note was reduced to $6,500,000 as a result of the payment of the initial installment of $1,000,000.  As required by GAAP, the note was discounted, after payment of the initial installment of $1,000,000, using a market discount rate of 28%, to a fair value of $5,517,536. The resulting discount of $982,464 was accreted over the life of the note using the effective yield method and recognized as interest expense. We expect interest expense to increase during the fiscal year ended April 30, 2013 as we seek funding to implement our operating and drilling plan.

Purchase or Sale of Equipment

To date there have not been any purchases or sales of equipment except as associated with our acquisitions of oil and gas properties. We anticipate that we will acquire equipment as we expand our offices in Texas. We may acquire other equipment in connection with our oil and gas business.

Liquidity and Capital Resources

We generally rely on cash generated from operations and, to the extent that credit and capital market conditions will allow, future public equity and debt offerings to satisfy our liquidity needs. Our ability to fund planned capital expenditures and to make acquisitions depends upon our future operating performance and more broadly, on the availability of equity and debt financing, which is affected by prevailing economic conditions in our industry and financial, business and other factors, some of which are beyond our control. We cannot predict whether additional liquidity from equity or debt financings will be available on acceptable terms, or at all, in the foreseeable future.
 
Our cash flow from operations is driven by commodity prices, production volumes and the effect of commodity derivatives – if we choose to purchase any such derivatives. Prices for oil and gas are affected by national and international economic and political environments, national and global supply and demand for hydrocarbons, seasonal influences of weather and other factors beyond our control. Cash flows from operations are primarily used to fund exploration and development of our oil and gas properties and corporate general and administrative expenses.
 
Recognizing we do not have adequate liquidity from cash generated from operations for current working capital needs and maintenance of our current drilling and acquisition program, we will need to access the public or private equity or debt markets for future development of reserves, acquisitions, additional working capital or other liquidity needs, if such financing is available on acceptable terms. We cannot guarantee that such financing will be available on acceptable terms or at all.
 
Going Concern Consideration
 
Our auditors included an explanatory paragraph in their report on the accompanying financial statements regarding expressing substantial doubt about our ability to continue as a going concern. Our financial statements contain additional note disclosures describing the circumstances that lead to this disclosure by our registered independent auditors.
 

Due to this doubt about our ability to continue as a going concern, management was open to new business opportunities which may prove more profitable to our shareholders.  Historically, we have been able to raise a limited amount of capital through private placements of our equity stock, but have been more successful as a result of the expanded business strategy. However, we are uncertain about our continued ability to raise funds privately. If we are unable to secure adequate capital to continue operations, our business may fail and our stockholders may lose some or all of their investment.

Liquidity and Capital Resources
 
We had a working capital deficit of $3,371,222 at October 31, 2012 versus $3,163,141 at April 30, 2012.  Our working capital deficit increased during six months ended October 31, 2012 due primarily to losses incurred in connection with operations partially offset by the conversion of a $500,000 note payable. Our loss from operations amounted to $6,315,610 for the six months ended October 31, 2012.
Our cash balance at October 31, 2012 was $66,988 as compared to $60,626 at April 30, 2012. The change in our cash balance is summarized as follows:
 
Cash balance at April 30, 2012
 
$
60,626
 
Sources of cash:
     
Cash provided by financing activities
 
825,000
 
Total sources of cash including cash on hand
 
885,626
 
Uses of cash:
     
Cash used in operating activities
 
(625,040
)
Cash used in investing activities
 
(193,598
Total uses of cash
 
(818,638
)
Cash balance at October 31, 2012
 
$
66,988
 
 
Net cash used in operating activities of $625,040 for the six months ended October 31, 2012 was attributable to our net loss adjusted for non-cash charges as presented in the consolidated statements of cash flows and changes in working capital as discussed above.
 
We have historically financed our business activities principally through issuances of common shares, promissory notes, convertible notes and common share purchase warrants issued in private placements. These financings are summarized as follows:
 
   
Six Months Ended
 
   
October 31,
 2012
   
October 31,
 2011
 
Proceeds from sale of common shares
 
$
1,950,000
   
$
1,560,000
 
Proceeds from promissory notes
   
     
1,500,000
 
Repayments of promissory notes
   
(1,250,000
   
(1,500,000
)
Proceeds from convertible notes
   
125,000
     
 
Partner distributions
   
     
(72,435
)
Net cash provided by (used in) financing activities
 
$
825,000
   
$
(1,487,565
)

The net proceeds of our equity and debt financings have been primarily used to satisfy working capital requirements and invest in oil and natural gas properties as well as to fund the operations of the Company.  These investments totaled $203,953 and $1,066,233 for the six months ended October 31, 2012 and 2011, respectively.

As of October 31, 2012, the Company had current assets of $198,616 consisting of $66,988 cash, $124,611 trade accounts receivable, $7,017 prepaid expenses and current liabilities of $3,569,838. The current liabilities consist of the convertible note payable of $2,427,368, accounts payable of $626,364, accrued liabilities of $109,877, amounts due to related party of $24,521, and interest payable of $255,890 and $125,818 in liabilities associated with our convertible notes payable. As of the Company’s year ended April 30, 2012, the Company had current assets of $1,428,470 and current liabilities of $4,591,611. The decrease in current liabilities between these two periods is primarily the result of the payment of a sellers note related to the acquisition of JHE Holdings, LLC.
 
As of October 31, 2012, the Company had a working capital deficit of $3,371,222 compared to a deficit of $3,163,141 as at April 30, 2012. We estimate that cash requirements of approximately $6,400,000 will be required for development and administration costs, and to fund working capital during the next twelve months. There can be no assurance that we will be successful in raising the required capital or that actual cash requirements will not exceed our estimates. Failure to raise needed financing could result in our having to discontinue our mining oil and gas development business.
 
 
As at October 31, 2012, we had a cumulative deficit of $19,054,400 compared to $11,248,483 as at April 30, 2012. We expect to incur further losses during the remainder of our fiscal year ending April 30, 2013.
 
On June 16, 2011, we raised $1,200,000 in a private placement of units. Each unit consists of one share of our common stock and one common share purchase warrant, which may be exercised to acquire one share of our common stock at an exercise price of $0.50 through June 15, 2013. The proceeds from the private placement were used to fund the acquisition of JHE Holdings, LLC from High Plains Oil, LLC and pay certain transaction costs.
 
In conjunction with the June 16, 2011 capital raise, we acquired JHE Holdings, LLC from High Plains Oil, LLC with a combination of cash and a seller finance note.  The promissory note had a principal balance of $7,500,000, $1,000,000 of which was paid at closing as consideration for our acquisition of JHE Holdings, LLC.  The note incurred an interest rate of 5% per annum.  Following the payment of $1,000,000 at the closing of our acquisition of JHE Holdings, LLC, and the promissory note included principle payments of $1,500,000 on September 1, 2011, $2,000,000 on December 31, 2011, and $1,500,000 on each of March 1, 2012 and the maturity date of June 1, 2012. The promissory note was paid in full effective June 1, 2012
 
On August 17, 2011, we closed a private placement of shares. Under the terms of the private placement, we issued 1,440,000 shares of our common stock at a price of $0.25 per share to Accredited Investors for total proceeds of $360,000.  The proceeds from the share issuance were used for general corporate purposes.
 
On September 14, 2011, we issued the 6% convertible notes in the total amount of $1,500,000. The notes are due and payable on September 14, 2014, with interest at the rate of 6% per annum accruing on the unpaid principal amount, compounded annually. The notes are convertible at the option of the holder into shares of our common stock at a conversion price of $1.50 per share.  The notes are redeemable prior to maturity at our option and can be prepaid  in whole or in part at any time without a premium or penalty, upon 5 business days’ notice; prior to which the holder of the 6% Note may convert the principal and interest into shares of our common stock.  The proceeds of the notes went to pay the balance of the $1,500,000 installment due on September 1, 2011 for the promissory note held by the James H. Edsel, Nancy Edsel, and James H. Edsel, Jr. (collectively, the “Edsels”) that we assumed pursuant to our acquisition of JHE Holdings, LLC (see Edsel Promissory Note below for more additional information).

On February 8, 2012, we issued 10% convertible notes in the aggregate principal amount of $2,750,000, subject to the terms of the Inter-Creditor Agreement. The 10% notes bear interest at the rate of 10% per annum on the unpaid principal balance, which is payable monthly in arrears on the first business day of each calendar month.  The 10% notes are due and payable on February 8, 2013 or at the election of the applicable holder on the earlier of (i) our closing of a financing transaction for aggregate proceeds in excess of $5,000,000, which excess amount shall be applied to the principal balance of the applicable holder’s note (based on the ratio of the principal amount of such holder’s note relative to the aggregate principal amount of all the notes issued on February 8, 2012); (ii) the sale or partial sale of JHE Holdings, LLC; (iii) the sale of all or substantially all of the assets of JHE Holdings, LLC; or (iv) an Event of Default (as defined in the notes issued on February 8, 2012).  The notes are convertible at the option of the holders into shares of our common stock on February 8, 2013 or upon the occurrence of one or more of the triggering events set forth in clauses (i), (ii), and (iii) above, at a conversion price of $1.50 per share. The proceeds of the note issuance were used to make a payment to the Edsels under the promissory note that we assumed pursuant to the acquisition of JHE Holdings, LLC, and the balance of the proceeds of the issuance were used for other general corporate purposes. (See Edsel Promissory Note below for additional information). On October 9, 2012 we entered into note extension agreements with the holders of the 10% notes whereby the holders agreed to extend the maturity date of the notes to September 30, 2014 on the closing of a $5,000,000 financing within ninety days of execution of the note extension agreements, or as extended by additional thirty day periods, which are to be granted at the sole discretion of the holders of the notes. As an incentive to enter into the note extension agreements, the holders of the notes were issued an aggregate amount of 250,000 shares of our common stock on execution of the note extension agreement and they will receive an additional aggregate amount of 250,000 shares of our common stock on closing of the $5,000,000 financing. Should the financing not occur within the ninety day period or within an extension period, then the original terms of the notes shall remain in effect.

On March 14, 2012, we issued 10% convertible notes for cash in the aggregate principal amount of $500,000, subject to the terms of the Addendum to March 2012 Convertible Note Subscription Agreement with the holder of the 10% convertible notes issued on March 14, 2012.  The note bears interest at the rate of 10% per annum on the unpaid principal balance, which is payable monthly in arrears on the first business day of each calendar month.  The note is due and payable on March 14, 2013 or at the election of the holder on the earlier of (i) our closing of a financing transaction for aggregate proceeds in excess of $5,000,000, which excess amount shall be applied to the principal balance of the holder’s note ; (ii) the sale or partial sale of JHE Holdings, LLC; (iii) the sale of all or substantially all of the assets of JHE Holdings, LLC; or (iv) an Event of Default (as defined in the note).  The note is convertible at the option of the holder into shares of our common stock on March 14, 2013 or upon the occurrence of one or more of the triggering events set forth in clauses (i), (ii), and (iii) above, at a conversion price of $1.50 per share. The proceeds of the note were used to make payments to Wevco Production, Inc.  The balance of the proceeds of the note was used for other general corporate purposes.
 

Effective March 14, 2012, we entered into an Addendum to March 2012 Convertible Note Subscription Agreement with the holder of the 10% convertible notes issued on March 14, 2012. The Addendum provides for, among other items that we use our best efforts to (i) the grant to the holder of the convertible note of a subordinated security interest in JHE Holdings, LLC, upon termination of the currently existing pledge and security interest JHE Holdings, LLC and any creditor with a senior security interest or right to a security interest in JHE Holdings, LLC existing as of the date of the Addendum, (ii) grant a security interest in our interest in certain oil and gas properties within the Redfish 56 Prospect in Glasscock County, Texas, and (iii) upon issuance of our shares of common stock to Mr. Pina under his employment agreement with us, as may be amended from time to time, Mr. Pina will pledge the shares that he receives under his employment agreement to secure payment of the note that we issued on March 14, 2012.

As of May 3, 2012, we issued 4,800,000 shares of common stock in connection with the exercise of 4,800,000 share purchase warrants as $0.50 per share. We received $2,400,000 in proceeds. We issued the warrants on June 15, 2011 in a private placement of 4,800,000 units at a price of $0.25 per unit; each unit consisted of one share of common stock and one common stock purchase warrant, exercisable to acquire one share of our common stock at an exercise price of $0.50 through June 15, 2013.

On May 15, 2012, we closed a private placement of units to an Accredited Investor. Under the terms of the private placement, we issued 500,000 units at a price of $1.50 per unit. Each unit consists of one share of our common stock and one half common share purchase warrant, each full warrant exercisable to purchase one share of our common stock at $2.75 for a period of three years. We raised $750,000 in the private placement. The proceeds were partially used to pay the final payment of the promissory note held by the Edsels, a payment to Wevco Production, Inc. and general corporate purposes.

On August 22 , 2012, we entered into a Debt Conversion Agreement with the holder of a $500,000, 10% convertible note due March 14, 2013 and G. Jonathan Pina. The note was convertible at $1.50 per share of our common stock. This note along with accrued interest in the amount of $15,615 was converted in exchange for 1,100,000 shares of our common stock. In connection with this conversion we have recorded a charge of $102,687 to interest expense related to the un-accreted portion of the debt discount as of the date of the conversion. We have recorded a loss of $406,334 on conversion related to the issuance of the 1,100,000 shares at $0.53. The conversion feature contained in the note as of the date of the notes inception indicated that the note was convertible into 333,333 shares of the Company’s company stock. To induce the conversion additional shares were issued to the noteholder and the value associated with these additional shares has resulted in the loss on conversion.

The foregoing description of the Debt Conversion Agreement is qualified in its entirety by reference to the copy of the Debt Conversion Agreement included as Exhibit 10.28 to the Form S-1 filed with the SEC on October 10, 2012.

On August 15, 2012, we entered into $550,000 convertible note agreement. The note matures on August 15, 2014. The terms of the note contain a 10% or $55,000 original issuance discount, to be pro-rated based on actual cash drawn in connection with the instrument. As of October 31, 2012, we have drawn $125,000 under the terms of the note and recorded an original issuance discount in the amount of $12,500 to be amortized over the term of the note resulting in a principal amount due the lender of $137,500. The note bore no interest for the first 90 days. The terms of the note indicate that if principal and interest are not re-paid within 90 days of the initial funding a onetime 10% interest charge was to be applied related to amounts borrowed. As of October 31, 2012, we accrued interest payable in the amount of $12,500. The note is convertible into shares of our common stock at the lesser of $0.55 or at a share value of 75% of the lowest closing share price for the 25 days preceding a conversion.

On October 9, 2012 the terms of our February 8, 2012 10% convertible notes were modified whereby interest payments were delayed through February, 2013, further should the Company close on a $5,000,000 financing the maturity date of these notes will be extended through September 30, 2014. In exchange for these modifications the Company issued the note-holders 250,000 shares of the Company’s common stock. In connection with the issuance of these common shares we have recognized a discount to the notes in the amount of $57,500. The discount related to this share issuance will be amortized over the remaining term of the notes. The remaining unamortized discount related to the beneficial conversion price and the share issuance of as of October 31, 2012 amounted to $322,632.

On November 15, 2012 we entered into a turnkey participation and operating agreement related to the drilling of an exploratory well in Trego County Kansas. The well is located within the Jayhawk prospect area in the Central Kansas uplift. The 1,440 acres on which the exploratory well is located, the “Lynd Acreage”, was acquired through an assignment from Wevco for consideration paid in the form of cash and common stock. In connection therewith we have drilled and are in the process of completing the well at this location.
 
On December 18, 2012, we entered into a Release and Settlement Agreement with Wevco Production Inc. Pursuant to the Release and Settlement Agreement, we issued 225,000 shares of our common stock  to Wevco Production Inc. and Wevco Production Inc released us from our obligations to return certain leases that had previously been assigned to us pursuant to our agreements with Wevco Production Inc. and released us from the requirement to pay certain delay rental payments as set forth in our agreements with Wevco Production Inc.
 

On December 18, 2012 we entered into a Payment Agreement with Big Sky Management Ltd. pursuant to which we issued 325,000 of our shares or common stock Common Shares to Big Sky Management Ltd. in lieu of making $100,000 worth of payments owed to Big Sky Management Ltd. for consulting services received since November 1, 2012 pursuant to a Consulting Agreement effective as of 15th day of June, 2011.

On January 2, 2013 we entered into a second turnkey participation and operating agreement related to the drilling of a second well on 160 acres in Trego County Texas.

We anticipate generating losses in the near term, and therefore, may be unable to continue operations in the future.  To secure additional capital, we will have to issue debt or equity or enter into a strategic arrangement with a third party.  There can be no assurance that additional capital will be available to us.  We currently have no agreements, arrangements, or understandings with any person to obtain funds through bank loans, lines of credit, or any other sources.

Working Capital for the fiscal year ended April 30, 2012 compared to the fiscal year April 30, 2011

Our working capital is affected primarily by our cash and cash equivalents balance, short term debt obligations, and our capital spending program. At April 30, 2012, we had a working capital deficit of $3,163,141, compared to a working capital deficit of $42,800 at April 30, 2011. The change in working capital for the fiscal year ended April 30, 2012 is primarily attributable to capital expended on drilling, operations, and acquisition support.

Cash Flows  for the fiscal year ended April 30, 2012 compared to the fiscal year April 30, 2011

The following table summarizes our sources and uses of funds for the periods noted.
 
   
2012
   
2011
 
 Cash flows used in operating activities
 
$
(625,707
)
 
$
(17,994
)
 Cash flows used in investing activities
   
(1,757,928
)
   
-
 
 Cash flows provided by financing activities
   
2,437,565
     
21,850
 
 Net increase in cash and cash equivalents
 
$
53,930
   
$
3,856
 

For fiscal year ended April 30, 2012, our primary sources of cash were from financing activities.  Approximately $7,510,000 of cash from financing activities were used to fund a portion of our drilling program and the various acquisitions executed during the fiscal year.

For fiscal year ended April 30, 2011, our primary sources of cash were from financing activities given we were a development stage company. Cash was invested on an as-needed basis by our shareholders or our management to continue company development efforts.

Operating Activities for the fiscal year ended April 30, 2012 compared to the fiscal year April 30, 2011

For the fiscal year ended April 30, 2012, cash flows used in operating activities increased by $607,713 from cash flows used in operating activities of $17,994 in the fiscal year ended April 30, 2011, primarily due to an increase in G&A expenses in the fiscal year ended April 30, 2012.

For the fiscal year ended April 30, 2011, our limited cash flows from operations and available cash were used primarily for developing the business plan and our strategy.

Investing Activities for the fiscal year ended April 30, 2012 compared to the fiscal year April 30, 2011

Cash used in investing activities increased by $1,757,928 for the fiscal year ended April 30, 2012, compared to the fiscal year ended April 30, 2011, which primarily reflects asset and lease acquisitions and extensions.  The majority of our cash flows used in investing activities for the fiscal years ended April 30, 2012 and April 30, 2011 have been used for drilling and acquisitions in Texas and Kansas.
 

The following table is a summary of capital expenditures related to our oil and gas properties.
 
   
2012
 
 JHE Holdings
 
$
1,000,000
 
 Redfish Prospect
   
193,717
 
 Leasehold
   
344,328
 
Cash from investment
   
(5,449
)
 Other
   
225,332
 
 Total
 
$
1,757,928
 

Financing Activities  for the fiscal year ended April 30, 2012 compared to the fiscal year April 30, 2011

We borrowed $11,250,000 under various credit agreements in the fiscal year ended April 30, 2012, compared to zero in the fiscal year ended April 30, 2011. We repaid a total of $5,000,000 of outstanding under our credit agreements during the fiscal year ended April 30, 2012.

Our goal is to manage our borrowings to help us maintain financial flexibility and liquidity.

2012 Capital Expenditures

In March 2012, we announced an agreement to acquire certain leasehold acreage from Wevco Production, Inc. Based upon subsequent amendments, we were obligated to pay $4,500,000 to Wevco Production, Inc. no later than September 28, 2012, to acquire these properties. We failed to make these payments and are currently in discussion with Wevco Production Inc. to amend the terms of the agreement.

In April 2012, we announced an agreement to acquire certain leasehold acreage from BlueRidge. Based upon subsequent amendments, we have the option to purchase additional acreage from BlueRidge in exchange for approximately $10,108,875 in cash and $1,000,000 of common stock payable to BlueRidge on or before September 28, 2012. The option expired unexercised.

As of April 30, 2012, we have authorizations for expenditure (“AFEs”) totaling $81,314 for our share in completion costs of new wells in which we share a working interest.  At present cash flow levels, we do not expect to have sufficient funds available for our share of both the outstanding AFEs and any additional acreage, seismic and/or drilling cost requirements that might arise from our existing opportunities.  We may alter or vary all or part of any planned capital expenditures for reasons including, but not limited to changes in circumstances, unforeseen opportunities, the inability to negotiate favorable acquisition, farm-out, joint venture or divestiture terms, commodity prices, lack of cash flow, and lack of additional funding.
 
We are continually evaluating drilling and acquisition opportunities for possible participation.  Typically, at any one time, several opportunities are in various stages of evaluation.  Our policy is to not disclose the specifics of a project or prospect, nor to speculate on such ventures, until such time as those various opportunities are finalized and undertaken.  We caution that the absence of news and/or press releases should not be interpreted as a lack of development or activity.
 
Our capital budget the fiscal year ended April 30, 2013 is subject to change depending upon a number of factors, including additional data on offsetting well results to our Kansas acreage drilling and recompletion results in our Texas operations, economic and industry conditions, prevailing and anticipated prices for oil, gas and NGLs, the availability of sufficient capital resources, our financial results and the availability of lease extensions and renewals on reasonable terms.

Contractual Obligations
 
On October 31, 2012, our contractual obligations include short-term debt, long-term debt, service contracts, operating lease obligations, acquisition contracts and employment agreements with our executive officers.
 
As of October 31, 2012 we had outstanding employment agreements with each of our two executive officers.  Our maximum cash commitment under the employment agreements was approximately $340,321 as of October 31, 2012, assuming the agreements were honored through the initial term and the executive was entitled to a change of control severance.
 
 
We took over a note payable in the amount of $7,500,000 for the purchase of JHE Holdings, LLC the former owners of JHE Holdings, LLC.  Upon closing of the transaction on June 16 and effective June 1, the note was reduced to $6,500,000 as a result of the payment of the initial installment of $1,000,000.  The note was further reduced to $5,000,000 after the payment of the September 1, 2011 installment of $1,500,000. The remaining installment payments due under the note payable are as follows: $2,000,000 on December 31, 2011; $1,500,000 on March 1, 2012; and 1,500,000 on June 1, 2012.  The note bears simple interest at 5.0%, which is payable quarterly.  The note was discounted, after payment of the initial installment of $1,000,000, using a rate of 28%, resulting in a fair value of $5,517,536. We received an extension from the note holder pursuant to the $1,500,000 payment due September 1, 2011 until September 15, 2011.  Full payment of the September 1 payment in the amount of $1,500,000 was made prior to September 15, 2011.
 
On July 26, 2011, we signed a 12-month contract beginning August 1, 2011, with Consolidated Asset Management Services (Texas), LLC (CAMS), to provide certain asset management support services with respect to business planning, accounting or other issues arising with respect to certain oil and gas assets. The payment schedule was structured as follows: a monthly payment of $11,000 for August – September; a monthly payment of 13,500 for October – December; a monthly payment of $16,000 for January; and a monthly payment of $13,500 for February and March.  The agreement was modified in March to reflect a monthly payment of $13,500 per month for the remaining term of the contract.
 
On September 14, 2011, we issued 6% convertible notes in the total amount of $1,500,000. The notes are due and payable on September 14, 2014, with interest at the rate of 6% per annum accruing on the unpaid principal amount, compounded annually.
 
On September 20, 2011, we signed a 12-month contract beginning October 1, 2011, with ChangeWave, Inc. dba NBT Communications, to provide:  shareholder acquisition and marketing consulting by means of a project roadmap; institutional investor targeting and presentation review and recommendations; NBT Research reports and updates; social media site management; Web Site/E-letter Sponsorships; NBT and broker dealer conferences; and financial media article/coverage program.  We pay a monthly fee of $6,000 per month.
 
On February 1, 2012, we signed a two-year lease with Wells Rental Properties LTD for approximately 1,325 square feet of office space located at 7065 Confederate Park Rd., Suite 102, Fort Worth, Texas. Our total lease payment is $1,300 per month.  The lease will expire January 31, 2014.
 
On February 8, 2012, we issued 10% convertible notes in the aggregate principal amount of $2,750,000.  These notes bear interest at the rate of 10% per annum on the unpaid principal balance; interest is to be paid monthly in arrears on the first business day of each calendar month. Pursuant to the note extension agreements, the accrued interest from June 1, 2012 until the closing of a $5,000,000 financing will be paid on closing of the financing.  Should the financing not close within ninety days or within the subsequent thirty day extension periods, the terms of the notes shall revert to their original terms.
 
On March 14, 2012, we issued a 10% convertible note for cash in the aggregate principal amount of $500,000, subject to the terms of the Addendum.  The note bears interest at the rate of 10% per annum on the unpaid principal balance; interest is to be paid monthly in arrears on the first business day of each calendar month. This note was converted into 1,100,000 shares of our common stock on August 22 , 2012.
 
 
The following chart provides an overview of our contractual obligations during the period from December 1 , 2012 through April 30, 2013, and from May 1, 2013 through April 30, 2015.
 
Obligations
 
Amount
   
Amount
 
   
December 1 , 2012
to April 30, 2013
($)
   
May 1, 2013
through April 30, 2015
($)
 
6% Convertible Notes due September 14, 2014 (i)
 
-
     
1,500,000
 
10% Convertible Notes due February 8, 2013 (ii)
 
2,750,000
     
-
 
Salary payments to G. Jonathan Pina (iii)
   
75,000
     
35,322
 
Salary Payments to S. Jeffrey Johnson (iv)
   
83,333
     
83,333
 
Confederate Park Office Space (v)
   
6,500
     
11,700
 
Consulting Agreement with Big Sky Management Ltd.
   
20,000
     
40,000
 
Total
 
$
2,934,833
   
$
1,670,355
 
 
(i) The 6% Convertible Notes are due and payable on September 14, 2014 and accrue interest at a rate of 6% per annum and payable at maturity.

(ii) The 10% Convertible Notes are due and payable on February 8, 2013 and pay interest at a rate of 10% per annum, payable monthly.

(iii) Monthly installments of $15,000 for a two-year term, beginning July 11, 2011.
 
(iv) Annual salary in the amount of 200,000 starting on October 1, 2011 with no set payment intervals for a two-year term.
 
(v) Two year lease for 1,325 square feet of office space commencing from January 1, 2012 through January 31, 2014 at $1,300 per month.

(vi) Monthly payments of $5,000 for a one year term starting January 1, 2013.

Off-Balance Sheet Arrangements

None.

General Trends and Outlook

Our financial results depend upon many factors, particularly our ability to raise capital and fund debt. The price of oil and gas also impacts our financial results.  Commodity prices are affected by changes in market demand, which is impacted by domestic and foreign supply of oil and gas, overall domestic and global economic conditions, commodity processing, gathering and transportation availability and the availability of refining capacity, price and availability of alternative fuels, price and quantity of foreign imports, domestic and foreign governmental regulations, political conditions in or affecting other gas producing and oil producing countries, weather and technological advances affecting oil and gas consumption. As a result, we cannot accurately predict future oil and gas prices, and therefore, we cannot determine what effect increases or decreases will have on our capital program, production volumes and future revenues. A substantial or extended decline in oil and gas prices could have a material adverse effect on our business, financial condition, results of operations, quantities of oil and gas reserves that may be economically produced and liquidity that may be accessed through the capital markets.
 
In addition to production volumes and commodity prices, finding and developing sufficient amounts of oil and gas reserves at economical costs are critical to our long-term success. Future finding and development costs are subject to changes in the industry, including the costs of acquiring, drilling and completing our projects. We focus our efforts on increasing oil and gas reserves and production while controlling costs at a level that is appropriate for long-term operations. Our future cash flow from operations will depend on our ability to manage our overall cost structure.

Like all oil and gas production companies, we face the challenge of natural production declines. Oil and gas production from a given well naturally decreases over time. Additionally, our reserves have a rapid initial decline. We attempt to overcome this natural decline by drilling to develop and identify additional reserves, farm-ins or other joint drilling ventures, and by acquisitions. However, during times of severe price declines, we may from time to time reduce current capital expenditures and curtail drilling operations in order to preserve liquidity. A material reduction in capital expenditures and drilling activities could materially reduce our production volumes and revenues and increase future expected costs necessary to develop existing reserves.
 
 
To fund our current working capital needs and maintain our current drilling and acquisition program, we must access the public or private equity or debt markets.  Also, additional capital is necessary for future development of reserves, acquisitions, additional working capital or other liquidity needs. We cannot guarantee that such financing will be available on acceptable terms or at all.
 
We anticipate generating losses in the near term, and therefore, may be unable to continue operations in the future.  To secure additional capital, we will have to issue debt or equity or enter into a strategic arrangement with a third party.  There can be no assurance that additional capital will be available to us.  We currently have no agreements, arrangements, or understandings with any person to obtain funds through bank loans, lines of credit, or any other sources.

 
Name and Incorporation
 
We were formed under the laws of the State of Nevada on May 21, 2007.
 
Our principal business office is located in the United States at 7065 Confederate Park Road, Suite 102, Forth Worth, Texas, 76109 and our telephone number is (817) 744-8502.
 
Overview of the Company

We are an early stage company that was incorporated on May 21, 2007. Up until June 2011, we had been a limited operations entity, primarily focused on organizational matters and developing an online help desk customer support system to assist service companies to improve their customer relationship management. In fiscal 2011, we continued to explore opportunities to diversify our business.

In June 2011, we changed our focus and undertook an acquisition of interests in oil and gas producing properties.  As a result of the acquisition, we are no longer in the development stage.  On June 2, 2011, David Brow replaced Felipe Pati, as our sole officer and was appointed as the President, Treasurer and Secretary. On June 6, 2011, Mr. Brow was elected as our sole director at the annual and special meeting of our shareholders. At the annual and special meeting, our shareholders voted in favor of changing our name to Circle Star Energy Corp. and amending and restating our bylaws.

On June 16, 2011, we filed a Certificate of Amendment to its articles of incorporation with the Secretary of State of Nevada changing our name from Digital Valleys Corp. to Circle Star Energy Corp., effective July 1, 2011. Effective July 1, our ticker symbol on the OTCBB was changed from “DTLV” to “CRCL.”

Current Operations

We are an oil and gas exploration and production company with minority stakes in several oil producing assets in Texas and Kansas . We have minority stakes include producing and non-producing oil and gas mineral interests, royalty interests, and working interests. In Kansas we are the operator of an exploratory drilling program.
 
We currently have minority stakes in several producing assets, located in several areas throughout Texas and Kansas :
·
Madisonville Woodbine Field (Madison/Grimes, County, Texas) – Woodbine;
·
Pearsall Field (Dimmit/Zavala County, Texas) – Austin Chalk , Eagle Ford Shale;
·
Permian Basin (Scurry/Crane/Glasscock et. al. County, Texas) – Wolfcamp, Clearfork, Spraberry, Fusselman, Cline Shale
Central Kansas Uplift (Trego County, Kansas)

These properties are operated on our behalf by several highly skilled companies:
·
Apache Corp. - NYSE: APA
·
Chesapeake Energy – NYSE: CHK
·
CML Exploration (formerly Patterson Exploration) – Private company
·
Leexus Oil & Gas– Private company;
·
Woodbine Acquisition Corp.- Private company

We are the operator of record in Kansas.
 
 
We intend to pursue acquisitions of property in Northwest Kansas, in the Mississippian Lime formation, located in South-central Kansas and North-central Oklahoma.  The Mississippian Lime is an older producing field with more than 30 years of production that is now being redeveloped using horizontal drilling and fracking techniques.  The play is estimated to span 17 million acres with oil in place estimates ranging from 5.4 to 5.9 billion barrels of oil equivalent (BBOE).

The formation is a shallow carbonate play (mostly Limestone) with depths ranging from 3,000' to 6,000'.  Because the Lime is shallower than other formations (such as the Bakken and Eagle Ford),  companies can use smaller drilling rigs, leading to significantly lower drilling and completion costs to commercially develop new producing wells.

JHE Acquisition

On June 16, 2011, we closed an acquisition under the terms of a Membership Interest Purchase Agreement, effective as of June 1, 2011 among High Plains Oil, LLC and JHE Holdings, LLC, pursuant to which we acquired all of the membership interests in JHE Holdings, LLC, a Texas limited liability company from High Plains Oil, LLC High Plains Oil, LLC is an entity controlled by S. Jeffrey Johnson, who was appointed as one of our directors on June 16, 2011 and Chairman of the Board on July 6, 2011. We were at arm’s length with Mr. Johnson prior to his appointment as a director.

In consideration for the acquisition of JHE Holdings, LLC, we agreed to among other requirements to: (a) issue 1,000,000 shares of our common stock to High Plains Oil, LLC; (b) pay the $1,000,000 installment payment due June 1, 2011, under a promissory note in the aggregate amount of $7,500,000 issued by High Plains Oil, LLC to the Edsels; (c) assume all future obligations and liabilities under the such promissory note; and (d) pledge our interest in JHE Holdings, LLC as collateral for full payment of the promissory note.

Redfish Properties Acquisition

On December 6, 2011, we entered into a letter agreement with Ingebritson Energy LLC, GTP Energy Partners, LLC, Wind Rush Energy, LLC, Gabriel Barerra and Charles T. Brackett with a stated execution date of December 1, 2011. The letter agreement is effective November 1, 2011. Pursuant to the letter agreement, we purchased certain interests in oil and gas properties within the Redfish 56 Prospect in Glasscock County, Texas. In return, the sellers received 203,571 shares of our common stock and we assumed the responsibility for payment of certain operating expenses and capital expenditures.

The foregoing description of the letter agreement is qualified in its entirety by reference to the copy of the letter agreement which is included as Exhibit 10.13 to the Form S-1 filed with the SEC on October 10, 2012

Wevco Acquisition

We entered into a leasehold purchase agreement with Wevco Production, Inc., whereby Wevco Production, Inc. will sell to us all of its rights, title, and working interest in and to certain oil and gas leases, containing up to 64,575 net acres, more or less, situated in Gove and Trego Counties, Kansas, described more fully in Exhibit A to our purchase agreement with Wevco Production, Inc. Under our purchase agreement with Wevco Production, Inc., we will pay to Wevco Production, Inc. $5,000,000 on or before closing and issue 1,000,000 shares of our common stock to Wevco Production, Inc. Contemporaneously with the signing of the purchase agreement, we paid Wevco Production, Inc., $100,000 and we paid Wevco Production, Inc. an additional $200,000 on or before March 13, 2012 (as amended to March 15, 2012). The aggregate payments of $300,000 are non-refundable and are considered an advance on the $5,000,000 purchase price. We issued the 1,000,000 shares of our common stock to Wevco Production, Inc. on March 15, 2012.
 
On April 24, 2012, we entered into an amendment to the purchase agreement with Wevco Production, Inc. extending the closing date from April 30, 2012 until May 31, 2012. We paid Wevco Production, Inc. a non-refundable $100,000 extension fee which is considered an advance on the $5,000,000 purchase price.

On June 13, 2012, we entered into the Second Amendment to Leasehold Purchase Agreement extending the closing date from May 31, 2012 until September 28, 2012. Pursuant to this amendment, we paid Wevco Production, Inc. a non-refundable $100,000 extension fee, and issued 600,000 shares of our common stock to Wevco Production, Inc. If the full purchase price of $5,000,000 is paid on or before the September 28, 2012 then the $500,000 that has already been paid to Wevco Production, Inc. will be credited towards the $5,000,000 Purchase Price.

We were not able to make the required $4,500,000 payment by September 28, 2012 and the option to purchase properties from Wevco Production Inc. expired. We are currently in discussion with Wevco Production, Inc. to amend the terms of our agreement.
 

The foregoing descriptions of the purchase agreement, amending agreement and second amendment to the purchase agreement with Wevco Production, Inc. are qualified in their entirety by reference to copies of such documents included as Exhibits 10.21, 10.24 and 10.25 to our Form S-1 filed with the SEC on October 10, 2012.
 
On December 18, 2012, we entered into a Release and Settlement Agreement with Wevco Production Inc. Pursuant to the Release and Settlement Agreement, we issued 225,000 shares of our common stock  to Wevco Production Inc. and Wevco us from our obligations to return certain leases that had previously been assigned to us pursuant to our agreements with Wevco Production Inc. and released us from the requirement to pay certain delay rental payments as set forth in our agreements with Wevco Production Inc.

BlueRidge Acquisition

On July 9, 2012, we entered into an amendment to a purchase and sale agreement with BlueRidge Petroleum Corporation, Walter F. Brown, Kirk T. and/or Rebecca L. Rundle as JTRS, First Equity Resources, LLC, G. Jeff Mowry and Marsha S. Mowry Trust Dated July 9, 2007, Harold C. Porter Family Trust, Bobbie D. Porter Living Trust dated December 13, 2004, Porter Oil Properties, LLC, OA Operating, Inc., and Swann Resources, Inc. The amendment amends the purchase and sale agreement entered into by the same parties on April 17, 2012.

Pursuant to the BlueRidge Purchase Agreement, we agreed to purchase certain interests in oil and gas leases in Rawlins, Sheridan and Graham Counties, Kansas, as more fully described in Exhibit A to the BlueRidge Purchase Agreement in return for $5,308,375 and 560,000 shares of our common stock, with a closing date of July 1, 2012. Pursuant to the purchase agreement dated April 17, 2012, we agreed to purchase interests in 17,168 acres in Rawlins County, 12,518 acres in Sheridan County 12,781 acres in Graham County.

The amendment modified the terms of the purchase agreement dated April 17, 2012 by reducing the acreage of the leases in Graham County by 1,760 acres, and by granting us an option to purchase the properties in Rawlins and Graham Counties. The amending agreement further modified the terms of the purchase agreement dated April 17, 2012, whereby we paid an aggregate of $50,000 to the sellers and issued 2,611,000 shares of our common stock to the sellers for their interests in Sheridan County.

Pursuant to the amending agreement dated July 9, 2012, we possess an option to purchase the remaining acreage owned by the respective sellers on or before September 28, 2012.  We will exercise this option only upon receiving sufficient funding.  We are pursuing all available funding alternatives including but not limited to a convertible debenture or unit (common stock with warrants) offering or a sale of assets; however, we cannot be sure our efforts will be successful in raising the necessary capital.

Pursuant to the amending agreement dated July 9, 2012, we have the option to purchase interests in 80,871 acres in Kansas (including the properties in the Rawlins and Graham Counties noted above), by making a cash payment of $10,108,875 and by delivering the number of our shares of common stock equal to $1,000,000, based on the market price of our shares of common stock on the date before closing of the option, on or before September 28, 2012.

We were not able to make the required payment by September 28, 2012, and the option to purchase properties pursuant to the BlueRidge Purchase Agreement expired.

The foregoing description of the purchase agreement and the amending agreement are qualified in their entirety by reference to copies of such documents included as Exhibits 10.26 and 10.27 to our Form S-1 filed with the SEC on October 10, 2012.

Edsel Promissory Note

Pursuant to the Amended and Restated Pledge and Security Agreement, we, effective as of the June 1, 2011, pledged 100% of the membership interests in JHE Holdings, LLC to the Edsels, including all rights and assets relating to such membership interests, as security for the payment and satisfaction of our obligations under the promissory note that we assumed as part of the acquisition of JHE Holdings, LLC.

Effective June 1, 2012, the Edsels and us entered into a Note Payment Agreement, whereby, we paid the Edsels $1,250,000 and conveyed to Orbis Energy, Ltd. certain interests in properties held by JHE Holdings, LLC that were operated by Encana.  The payment of $1,250,000 and the conveyance of the Encana Properties resulted in the promissory note held by the Edsels to be fully paid, and we were released from any further obligations to the Edsels under the promissory note, the Amended and Restated Pledge and Security Agreement and the Novation Agreement. See Note 7 to our Consolidated Financial Statements for the year ended April 30, 2012 for more information on the promissory note held by the Edsels.
 

Financings

See section entitled “Liquidity” above for information on our financing activities.
 
Employees

Mr. Pina was appointed as Chief Financial Officer, effective July 11, 2011.  Mr. Johnson was appointed as Chief Executive Officer on October 11, 2012. We retained consultants to assist with general and administrative support and anticipates it will hire additional employees during the fiscal year ending April 30, 2013. We also employ one administrative staff member and a vice-president of operations for a total of four employees.

Competition

The oil and gas industry is intensely competitive. We compete with numerous individuals and companies, including many major oil and gas companies, which have substantially greater technical, financial and operational resources. Accordingly, there is a high degree of competition for desirable oil and gas assets, as well as for access to funds. There are other competitors that have operations in our focus areas and the presence of these competitors could adversely affect our ability to acquire additional assets.

Government Regulations

The development of oil and gas properties is subject to various United States federal, state and local governmental regulations. The properties in which we own an interest may, from time to time, be required to obtain licenses and permits from, or to pay certain bonds to, various governmental authorities in regards to the development of the properties. We currently do not serve as an operator on any of the oil and gas properties held by JHE Holdings, LLC. Instead, JHE Holdings, LLC holds non-operated working interests, royalty, and mineral interests on properties operated by others. The descriptions below relate to regulations as they may affect the operations of these operators and our interests in these properties.

Regulations affecting production

Texas and Kansas, the states that are properties are located in and where we intend to acquire additional properties, generally require drilling permits for drilling operations, bonds and reports concerning operations and imposes other requirements relating to the development, drilling and production of oil and gas.  Texas and Kansas also have statutes or regulations addressing conservation matters, including provisions for the unitization or pooling of oil and gas properties, the establishment of maximum rates of production from oil and gas wells, the spacing, plugging and abandonment of such wells, restrictions on venting or flaring natural gas and requirements regarding the oil and gas industry.

These laws and regulations may limit the amount of oil and natural gas we can produce from our wells and may limit the number of wells or the locations at which we can drill. Moreover, many states impose a production or severance tax with respect to the production and sale of oil and natural gas within their jurisdiction. States do not generally regulate wellhead prices or engage in other, similar direct economic regulation of production, but there can be no assurance they will not do so in the future.

In the event operations are conducted on federal, state or Indian oil and natural gas assets, oil and gas operations may be required to comply with additional regulatory restrictions, including various nondiscrimination statutes, royalty and related valuation requirements, and on-site security regulations and other appropriate permits issued by the Bureau of Land Management (“BLM”) or other relevant federal or state agencies.

Regulations affecting sales

The sales prices of oil, natural gas liquids and natural gas are not presently regulated, but rather are set by the market. We cannot predict, however, whether new legislation to regulate the price of energy commodities might be proposed, what proposals, if any, might actually be enacted by Congress or the various state legislatures, and what effect, if any, the proposals might have on the operations of the underlying properties.

Under the Energy Policy Act of 2005, the Federal Energy Regulatory Commission (“FERC”) possesses regulatory oversight over natural gas markets, including the purchase, sale and transportation of natural gas by “any entity.” The Commodity Futures Trading Commission (“CFTC”) also holds authority to monitor certain segments of the physical and futures energy commodities market pursuant to the Commodity Exchange Act. With regard to physical purchases and sales of natural gas, natural gas liquids and crude oil, gathering of these energy commodities, and any related hedging activities, operators are required to observe these anti−market manipulation laws and related regulations enforced by FERC and/or the CFTC. These agencies hold substantial enforcement authority, including the ability to assess civil penalties of up to $1 million per day per violation, to order disgorgement of profits and to recommend criminal penalties.  Should operators violate the anti−market manipulation laws and regulations, they could also be subject to related third-party damage claims by, among others, sellers, royalty owners and taxing authorities.
 

The price from the sale of oil and natural gas liquids is affected by the cost of transporting those products to market. The FERC regulates interstate natural gas transportation rates and service conditions, which affect the marketing of gas we produce, as well as the revenues we receive. The price and terms of access to pipeline transportation are subject to extensive federal and state regulation. The FERC is continually proposing and implementing new rules and regulations affecting interstate transportation. These initiatives also may affect the intrastate transportation of natural gas under certain circumstances. The stated purpose of many of these regulatory changes is to promote competition among the various sectors of the natural gas industry.

Interstate transportation rates for oil, natural gas liquids and other products are also regulated by the FERC. The FERC has established an indexing system for such transportation, which allows such pipelines to take an annual inflation−based rate increase. We are not able to predict with any certainty what effect, if any, these regulations will have on us, but, other factors being equal, the regulations may, over time, tend to increase transportation costs which may have the effect of reducing wellhead prices for oil and natural gas liquids.

Environmental Matters

Oil and Gas Development Business
 
Operations pertaining to oil and gas development, production and related activities are subject to numerous and constantly changing federal, state and local laws governing the discharge of materials into the environment or otherwise relating to environmental protection.  These laws and regulations may require the acquisition of certain permits prior to or in connection with operations, restrict or prohibit the types, quantities and concentration of substances that oil and gas operators can release into the environment, restrict or prohibit activities that could impact wetlands, endangered or threatened species or other protected areas or natural resources, require some degree of remedial action to mitigate pollution from former operations, such as pit cleanups and plugging abandoned wells, and impose substantial liabilities for pollution resulting from operations. Such laws and regulations may substantially increase the cost of operations and may prevent or delay the commencement or continuation of a given project and thus generally could have a material adverse effect upon our revenue.

We believe that the oil and gas operators for our interests are in substantial compliance with current applicable environmental laws and regulations, and the cost of compliance with such laws and regulations has not been material and is not expected to be material during 2012-2013.
 
Nevertheless, changes in existing environmental laws and regulations or in the interpretations thereof could have a significant impact on the operations of our properties, as well as the oil and gas industry in general. For instance, any changes in environmental laws and regulations that result in more stringent and costly waste handling, storage, transport, disposal or clean−up requirements could have a material adverse impact on our revenue.
 
Hazardous Substances
 
The Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), also known as the “Superfund” law, imposes liability, without regard to fault or the legality of the original conduct, on certain classes of persons that are considered to have contributed to the release of a “hazardous substance” into the environment. These persons include the owner or operator of the disposal site or the site where the release occurred and companies that disposed or arranged for the disposal of the hazardous substances at the site where the release occurred. Under CERCLA, such persons 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 neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the hazardous substances released into the environment.
 
Currently we do not act as operator on any of our assets. Notwithstanding our lack of direct control over wells operated by others, the failure of an operator other than us to comply with applicable environmental regulations may, in certain circumstances, be attributed to us. We are not aware of any liabilities for which we may be held responsible that would materially and adversely affect us.
 
Waste Handling
 
The Resource Conservation and Recovery Act (“RCRA”), and analogous state laws, impose detailed requirements for the handling, storage, treatment and disposal of hazardous and solid wastes. RCRA specifically excludes drilling fluids, produced waters, and other wastes associated with the development or production of crude oil, natural gas or geothermal energy from regulation as hazardous wastes.  However, these wastes may be regulated by the U.S. Environmental Protection Agency (“EPA”) or state agencies as solid wastes. Moreover, many ordinary industrial wastes, such as paint wastes, waste solvents, laboratory wastes and waste compressor oils, are regulated as hazardous wastes.  Oil and gas operators are subject to compliance risks under RCRA in connection with their operations.
 
 
 
Air Emissions
 
The Federal Clean Air Act and comparable state laws and regulations impose restrictions on emissions of air pollutants from various industrial sources, including compressor stations and natural gas processing facilities, and also impose various monitoring and reporting requirements. Such laws and regulations may require that operators obtain pre−approval for the construction or modification of certain projects or facilities expected to produce air emissions or result in the increase of existing air emissions, obtain and strictly comply with air permits containing various emissions and operational limits, or utilize specific emission control technologies to limit emissions. An operator's failure to comply with these requirements could subject it to monetary penalties, injunctions, conditions or restrictions on operations, and potentially criminal enforcement actions.  Capital expenditures for air pollution equipment may be required in connection with maintaining or obtaining operating permits and approvals relating to air emissions at facilities in which our properties are located. The cost of compliance could have a material adverse consequence on our revenue.

Water Discharges
 
The Federal Water Pollution Control Act (“Clean Water Act”) and analogous state laws impose restrictions and strict controls with respect to the discharge of pollutants, including spills and leaks of oil and other substances, into waters of the United States.  The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by EPA or an analogous state agency. Federal and state regulatory agencies can impose administrative, civil and criminal penalties for non−compliance with discharge permits or other requirements of the Clean Water Act and analogous state laws and regulations. In addition, the United States Oil Pollution Act of 1990 (“OPA”) and similar legislation enacted in Texas, Louisiana and other coastal states impose oil spill prevention and control requirements and significantly expand liability for damages resulting from oil spills. OPA imposes strict and, with limited exceptions, joint and several liabilities upon each responsible party for oil spill response and removal costs and a variety of public and private damages.
 
Global Warming and Climate Change
 
In response to recent studies suggesting that emissions of carbon dioxide and certain other gases may be contributing to warming of the Earth’s atmosphere, the U.S. Congress is considering adoption of climate change−related legislation that would restrict emissions of “greenhouse gases.” One bill approved by the Senate Committee on Environment and Public Works would require a 70% reduction in emissions of greenhouse gases from sources within the United States between 2012 and 2050. In addition, at least 20 states have already taken legal measures to reduce emissions of greenhouse gases, primarily through the planned development of greenhouse gas emission inventories and/or regional greenhouse gas cap and trade programs. In California, for example, the California Global Warming Solutions Act of 2006 required the California Air Resources Board to adopt regulations by 2012 that would achieve an overall reduction in greenhouse gas emissions from all sources in California of 25% by 2020. Also, as a result of the U.S. Supreme Court’s decision on April 2, 2007 in Massachusetts, et al. v. EPA, the EPA may be required to regulate carbon dioxide and other greenhouse gas emissions from mobile sources (e.g., cars and trucks) even if Congress does not adopt new legislation specifically addressing emissions of greenhouse gases.
 
Depending on the legislation or regulatory program that may be adopted to address emissions of greenhouse gases, oil and gas operators could be required to reduce greenhouse gas emissions resulting from its operations or oil and gas operators could be required to purchase and surrender allowances for greenhouse gas emissions associated with its operations or the oil and gas it produces.
 
Business Strategy
 
Our business strategy is to continue to expand our reserve base and increase production and cash flow through the continued development of our assets and the possible acquisition of producing oil and natural gas properties.
 

Executive Offices
 
Our principal executive office is at 7065 Confederate Park Road, Suite 102, Forth Worth, Texas 76108.  We pay $1,300 per month. We do not currently own investments in real estate, real estate mortgages or securities of persons primarily engaged in real estate activities, nor do we expect to do so in the foreseeable future.
 
 
Oil and Gas Properties

We own royalty, non-operated working interests and mineral interests in certain oil and gas properties in Texas. The Oil and Gas Properties include producing wells in the TXL Extension, Crane County, TX (1.00% working interest and 0.75% revenue interest in two wells); Bullard Prospect, Scurry County, TX (1.25% – 2.50% working interest and 0.94% – 2.08% revenue interest in nine wells); Nursery Prospect, Victoria County, TX (2.75% working interest and 2.00% – 2.10% revenue interest in two wells); Pearsall Prospect, Dimmit and Zavala Counties, TX (0.24% - 5.00% working interest and 0.17% – 3.75% revenue interest in 25 wells); Madison Woodbine, Grimes and Madison Counties, TX (0.00% - 2.90% working interest and 0.0190% – 2.90% revenue interest in seven wells); Giddings Field, Fayette and Lee Counties, TX (0.00% - 3.00% working interest and 0.76% – 2.28% revenue interest in six wells); and the Glass Prospect in Glasscock County, TX (3.17% working interest in four wells).

County and Well Information
 
Texas County
 
Producing Wells*
   
Net Well Count
 
Crane
   
2.00
     
0.02
 
Dimmit
   
11.00
     
0.08
 
Fayette
   
6.00
     
0.15
 
Glasscock
   
 4.00
     
 0.13
 
Grimes
   
3.00
     
0.02
 
Madison
   
4.00
     
0.11
 
Scurry
   
9.00
     
0.19
 
Victoria
   
3.00
     
0.07
 
Zavala
   
14.00
     
0.05
 
Total*
   
56.00
     
0.82
 
                 
*Does not include interests in saltwater disposal wells.
 

Permian Basin:

The Permian Basin is an oil field located in West Texas and the adjoining area of southeastern New Mexico. The Permian Basin Oil Field covers an area approximately 250 miles wide and 300 miles long. Various zones and terms such as the Avalon Shale, Leonard Shale, Spraberry Formation, Yeso Oil Play, Bone Spring Formation &Wolfcamp Shale are all part of the Permian Basin.
 
Bullard Prospect (Scurry County, TX) is a producing oil/gas field located in Scurry County, Texas which is located in the Permian Basin in West Texas. We own a 1.25% - 2.50% working interest (0.9375% - 2.0833% net revenue interest) in nine oil/gas wells producing out of the Clear Fork and Glorietta formations at an approximate depth of 3,800 to 3,900 feet. Further, the operator may drill in 5-6 more locations in the Bullard Prospect in the next 12 months. As of January 3, 2011, the operator had identified approximately 6-10 undeveloped locations in the Bullard Prospect. We have interests in wells located in the Bullard Prospect operated by Unitex Oil & Gas. We hold interests in 2,962.7 gross acres, 762.7 of which is undeveloped, and 73.1 net acres, 69.1 of which is undeveloped.
 
TXL Extension (Crane County, TX) is a producing oil/gas field located in Crane County, Texas, which is located in the Permian Basin in West Texas. We have interests in wells located in the TXL Extension operated by CML Exploration, LLC. We own a 1.00% working interest (0.75% net revenue interest) in two wells producing out of the Wolfcamp formation at an approximate depth of 8,000 to 9,000 feet. We hold interests in 80.00 gross acres and 0.80 net acres in the TXL Extension.
 
Eagle Ford Shale
 
The Eagle Ford Shale is located in South Texas.  The formation produces from various depths between 4,000 and 12,000 feet. The Eagle Ford Shale takes its name from the town of Eagle Ford Texas where the shale outcrops at the surface in clay form.
 
The Eagle Ford Shale is a geological formation directly beneath the Austin Chalk limestone and it is considered to be the “source rock”, or the original source of hydrocarbons that are contained in the Austin Chalk.
 
We have interests in wells in the Pearsall Prospect which is a producing oil field located around and between Crystal City and Carrizo Springs, Texas, located in south Texas  The wells in which we have an interest are located in Dimmit and Zavala counties.
 
Dimmit County, TX
 
Dimmit County is situated in South Texas where companies are targeting oil, condensate, and gas. Dimmit County produces from both the condensate rich and oil prone areas of the Eagle Ford.
 
 
Zavala County, TX
 
Zavala County is in South Texas and forms part of the Eagle Ford Shale Oil Play. The county lies within the Maverick Basin where oil & gas companies are targeting the Eagle Ford Shale and the Pearsall Shale Gas Play.  Drilling in the Eagle Ford targets depths of 4,000 ft to 6,000 feet in the central and southern portions of the county.

Pearsall Prospect
 
The Pearsall field was originally discovered in the 1930’s and is part of a major oil-producing trend that stretches from near the Texas/Mexico border to the Texas/Louisiana border. Our Eagle Ford interests in the Pearsall Prospect are operated by Chesapeake Energy Corporation (“Chesapeake”). We own interests in various non-producing overriding royalty interest in the Eagle Ford Shale, which is a deeper, productive formation located in the same geographic area below the Austin Chalk formation and is generally considered to be the “source rock” for much of the regional production. Chesapeake has permitted 13 Eagle Ford wells on the acreage in which we own an average overriding royalty interest of 0.16% across 25,000 acres, and 7 wells have been, or are currently being drilled on the aforementioned asset. In addition, we own a 1.00% overriding royalty interest in 3,200 acres operated by Chesapeake.  Chesapeake has permitted 13 Eagle Ford wells on the acreage in which we own an average overriding royalty interest of 0.16% across 25,000 acres, and 7 wells have been, or are currently being drilled on the aforementioned asset.  In addition, we own a 1.0% overriding royalty interest in 3,200 acres operated by Chesapeake.
 
Approximately 50% of the horizontal drill wells in the world have been drilled in the Austin Chalk.  The Austin Chalk is a prolific reservoir that has been developed with vertical and horizontal drilling techniques. Our Austin Chalk wells in the Pearsall Prospect are operated by CML Exploration, LLC. We own a 0.24% - 5.00% working interest (0.17% - 3.75% net revenue interest) in 18 oil wells producing out of the Austin Chalk and Buda formations at an approximate depth of 6,000 to 7,100 feet. We hold interests in gross acres of 36,687.53 and net acres of 90.2365 in the Pearsall Prospect. Oil and natural gas production from this area is 40 degrees-gravity oil and 1,200 - 1,600 BTU natural gas. We also own interests in various non-producing overriding royalty interests in the Eagle Ford Shale, which is a deeper, productive formation located in the same geographic area (see Eagle Ford Pearsall Prospect).
 
Nursery Prospect
 
Nursery Prospect (Victoria County, TX) is a producing gas field located in Victoria County, Texas. The Nursery Prospect is situated in an area that has exhibited excellent gas and very good associated condensate production. We own a 2.75% working interest (2.00% - 2.10% net revenue interest) in two gas wells producing out of the Frio and Miocene formations at an approximate depth of 4,400 to 6,000 feet. Our wells located in the Nursery Prospect are operated by CML Exploration, LLC. We hold interests in 8,000 gross acres and 220 net acres in the Nursery Prospect.
 
Madisonville Woodbine Prospect
 
Madisonville Woodbine Prospect (Grimes and Madison Counties, TX) is a producing oil field located south of Madisonville, Texas. We own a 0.00% - 2.90% working interest (0.019% - 2.90% net revenue interest) in seven oil wells producing out of the Woodbine formation at an approximate depth of 7,800 to 9,000 feet. We acquired these interests via an acquisition which enjoins mineral and working interests in the Madisonville Woodbine Prospect through perpetual mineral deeds. Our wells located in the Madisonville Woodbine Prospect are currently operated by CML Exploration and Woodbine Acquisition Corp.  We hold interests in 3,466.23 gross acres and 43.97 net acres in the Madisonville Woodbine Prospect. We own approximately a 5.00% net revenue interest in the Oltmann Unit #1. Oil and natural gas production from this area is 40 degrees - gravity oil and 1,200 - 1,400 BTU natural gas. We also owns an interest in WAC's Camp #1 well which is undergoing completion and in several undeveloped horizontal Woodbine locations.

Giddings Field
 
Giddings Field (Fayette and Lee Counties, TX) is a producing oil field across several counties in South Central Texas. The Giddings field was rapidly exploited in the 1970’s and eventually expanded to include a long, narrow trend which extends from the Texas-Mexico border up through northeast Texas into Louisiana. The primary producing reservoir is the Austin Chalk which produced over 1 Billion BOE through vertical development and then underwent massive horizontal development beginning in the early 1990’s, with secondary production from the Taylor and deeper Buda and Georgetown formations. We own a 0.00% - 3.00% working interest (0.76% - 2.28% net revenue interest) in six oil wells producing out of the Austin Chalk formation at an approximate depth of 7,800 to 9,000 feet. Our wells in Giddings field are operated by Leexus Oil LLC. We hold interests in 1,766.13 gross acres and 54.25 net acres in Giddings field.
 

Glass Prospect

Glass Prospect (Glasscock County, TX) is project area encompasses 1,280 gross acres and 640 net mineral acres located in the oil-rich Permian basin region and is operated by Apache Corporation (“Apache”). The operator has already drilled 4 Spraberry wells and is evaluating the potential for additional development. Covering 2,500 square miles and six Texas counties, the Spraberry Formation is one of the largest in the nation for total proved reserves. The formation produces oil from a single enormous sedimentary unit located between the depths of 5,100 and 8,300 feet. In 2007, the U.S. Department of Energy ranked the Spraberry Trend third in the United States by total proved reserves and seventh in total production. Estimated reserves for the entire Spraberry-Dean unit exceed 10 billion barrels. To-date the formation has produced an estimated one billion barrels of oil. While development on the Glass Prospect leases has focused on the Spraberry formation to-date, the project is prospective for both Fusselmen and Cline Shale opportunities.  Apache is actively drilling horizontal Cline shale wells in the same field as the Glass prospect, and a recent Cline well drilled by Apache produced 8,800 Bbl of oil equivalent in the first 30 days on-line.

Central Kansas Uplift

Central Kansas Uplift (Trego County, Kansas), “Jayhawk” is a project area that encompasses 1,440 net acres located in the Central Kansas uplift. We are the operator of record for this project. To date we have drilled one exploratory well and are in the process of completing this well.

Delivery Commitments
 
We are not obligated to provide a fixed and determinable quantity of oil or gas in the future under existing contracts or agreements.

Competition

The oil and gas industry is intensely competitive, particularly with respect to the acquisition of prospective oil and natural gas properties and oil and natural gas reserves. Our ability to effectively compete is dependent on our geological, geophysical and engineering expertise, and our financial resources. We must compete against a substantial number of major and independent oil and natural gas companies that have larger technical staffs and greater financial and operational resources than we do. Many of these companies not only engage in the acquisition, development and production of oil and natural gas reserves, but also have refining operations, market refined products and generate electricity. We also compete with other oil and natural gas companies to secure drilling rigs and other equipment necessary for drilling and completion of wells. Consequently, drilling equipment may be in short supply from time to time. Currently, access to additional drilling equipment in certain regions is difficult.
 
Commodity Price Environment
 
Generally, the demand and the price of natural gas increases during the colder winter months and decreases during the warmer summer months.  Pipelines, utilities, local distribution companies and industrial users utilize natural gas storage facilities and purchase some of their anticipated winter requirements during the summer, which can lessen seasonal demand fluctuations. Crude oil and the demand for heating oil are also impacted by seasonal factors, with generally higher prices in the winter. Seasonal anomalies, such as mild winters, sometimes lessen these fluctuations.

Our results of operations and financial condition are significantly affected by oil and natural gas commodity prices, which can fluctuate dramatically. Commodity prices are beyond our control and are difficult to predict. We do not currently hedge any of our production.
 
The prices received for domestic production of oil and natural gas have been volatile and have resulted in increased demand for the equipment and services that we need to drill, complete and operate wells. Shortages have developed, and we have seen an escalation in drilling rig rates, field service costs, material prices and all costs associated with drilling, completing and operating wells. If oil and natural gas prices remain high relative to historical levels, we anticipate that the recent trends toward increasing costs and equipment shortages will continue.
 

Oil and Gas Reserves
 
Estimates of Proved Oil and Gas Reserves
 
Estimates of our proved reserves included in this report are prepared in accordance with U.S. generally accepted accounting principles, or GAAP, and SEC guidelines. The accuracy of a reserve estimate is a function of:
 
 
 
the quality and quantity of available data;

 
 
the interpretation of that data;

 
 
the accuracy of various mandated economic assumptions;

 
 
the judgment of the persons preparing the estimate.
 
Our proved reserve information included in this report was based on evaluations prepared by independent petroleum engineers. Estimates prepared by other third parties may be higher or lower than those included herein. Because these estimates depend on many assumptions, all of which may substantially differ from future actual results, reserve estimates will be different from the quantities of oil and gas that are ultimately recovered. In addition, results of drilling, testing and production after the date of an estimate may justify material revisions to the estimate.
 
In accordance with SEC requirements, we based the estimated discounted future net cash flows from proved reserves on the un-weighted arithmetic average of the prior 12-month commodity prices as of the first day of each of the months constituting the period and costs on the date of the estimate. In prior years, such estimates had been based on year end prices and costs. Future prices and costs may be materially higher or lower than these prices and costs which would impact the estimated value of our reserves.

The estimates of proved reserves materially impact DD&A expense. If the estimates of proved reserves decline, the rate at which we record depreciation and depletion expense will increase, reducing future net income. Such a decline may result from lower market prices, which may make it uneconomic to drill for and produce higher cost fields.

Proved Oil and Gas Reserves
 
The following table sets forth summary information regarding our estimated proved reserves, PV-10, and a reconciliation of PV-10 to the Standard Measure as of April 30, 2012. See Note 11 to our consolidated financial statements in this report for additional information. Our reserve estimates and our calculation of Standard Measure and PV-10 are based on the 12-month average of the first day of the month pricing of $94.23 per Bbl of West Texas Intermediate posted oil price and $3.54 per MMBtu Henry Hub spot natural gas price from May 1, 2011 through April 30, 2012.  Our estimated total proved reserves of oil and natural gas as of April 30, 2012 were 71,900 Boe, made up of 97% oil and 3% natural gas. The proved developed portion of total proved reserves at year end 2011 was 87.6%. Natural gas is converted at a rate of six Mcf of gas to one barrel of oil equivalent (“Boe”).
 
Reserves Category
 
Oil (Bbls)
   
Gas (Mcf)
   
Boe
   
Percent (%)
   
PV-10
 
 Proved Developed
                             
 JHE
   
32,990
     
168,240
     
61,030
     
84.9
%
 
$
1,720,140
 
 Redfish Properties
   
1,655
     
1,890
     
1,970
     
2.7
%
   
69,940
 
 Proved Undeveloped
                                       
 JHE
   
7,970
     
5,580
     
8,900
     
12.4
%
   
361,630
 
 Total Proved Reserves
   
42,615
     
175,710
     
71,900
     
100.0
%
   
2,151,710
 
                                         
 Standardized measure of discounted future net cash flows
                                 
$
2,151,710
 

PV-10 is our estimate of the present value of future net revenues from proved oil and gas reserves after deducting estimated production and ad valorem taxes, future capital costs and operating expenses, but before deducting any estimates of future income taxes. PV-10 is a non-GAAP, financial measure and generally differs from the Standardized Measure, the most directly comparable GAAP financial measure, because it does not include the effects of income taxes on future cash flows. PV-10 should not be considered as an alternative to the Standardized Measure as computed under GAAP.
 
 
We believe PV-10 to be an important measure for evaluating the relative significance of our oil and gas properties and that the presentation of PV-10 provides useful information to investors because it is widely used by professional analysts and sophisticated investors in evaluating oil and gas companies. Because there are many unique factors that can impact an individual company when estimating the amount of future income taxes to be paid, we believe the use of a pre-tax measure is valuable for evaluating our company. We believe that most other companies in the oil and gas industry calculate PV-10 on the same basis.
 
Changes to Proved Reserves
 
The following table sets forth the changes in our proved reserve volumes by operating area during the year ended April 30, 2012 (in Boe).
 
Operating Area
 
Production
   
Extensions and Discoveries
   
Purchases of Minerals in Place
   
Revisions to Previous Estimates
 
 JHE
   
(18,104
)
   
17,003
     
101,257
     
(30,214
)
 Redfish Properties
   
(194
)
   
-
     
1,131
     
1,021
 
 Total
   
(18,298
)
   
17,003
     
102,388
     
(29,193
)
 
We produced 18,298 Boe during 2012, 99% of which is attributable to the assets in JHE Holdings, LLC. Extensions and discoveries for 2012 of 16,853 Boe are all attributable to the assets in JHE Holdings, LLC. During 2012, we purchased approximately 102,388 Boe of proved reserves through our acquisition of JHE and certain oil and gas properties within the Redfish 56 Prospect in Glasscock County, Texas. We also recorded downward revisions in 2012 of 29,193 Boe, including 30,214 attributable to JHE Holdings, LLC, partially offset by 1,021 Boe of positive revisions attributable to certain oil and gas properties within the Redfish 56 Prospect in Glasscock County, Texas.
 
Preparation of Proved Reserves Estimates
 
Internal Controls Over Preparation of Proved Reserves Estimates
 
Our policies regarding internal controls over the recording of reserve estimates require reserve estimates to be in compliance with SEC rules, regulations and guidance.  All of our reported oil and natural gas reserves have been estimated as of April 30, 2012, by the LaRoche Petroleum Consultants, Ltd. (“LRPC”) of Richardson, Texas.  As of April 30, 2011, LRPC estimated reserves for all properties owned by us, which were located in Texas, comprising 100% of the PV-10 of our oil and gas reserves as of that date.  LRPC is an independent petroleum engineering consulting firm that has been providing petroleum consulting services throughout the world for over thirty years.  The average experience level of the staff at LPRC exceeds 35 years with major and independent oil company backgrounds.  LRPC is employee owned and maintains offices in Richardson, Texas.  The office of LRPC that prepared our reserves estimates is registered in the state of Texas (License # F-1360).  LRPC prepared our reserve estimate based upon a review of property interests being appraised, historical production, lease operating expenses and price differentials for our wells.  Additionally, authorizations for expenditure ("AFEs"), geological and geophysical data, and other engineering data that complies with SEC guidelines are among that which we provide to such engineer for consideration in estimating our underground accumulations of crude oil and natural gas.  This information was reviewed by G. Jonathan Pina, our Chief Financial Officer and S. Jeffrey Johnson, our President and Chief Executive Officer, to ensure accuracy and completeness of the data prior to and after submission to LRPC.  Mr. Pina received a Bachelor of Arts degree from Rice University and a Master of Business Administration from the Jesse H. Jones School, Rice University and has worked in the oil and gas industry for over seven years.  Mr. Johnson has worked in the oil and gas industry for over 23 years and has been a chief executive of a public oil and gas company for over six years.
 
The reports of LRPC dated June 8, 2012 and June 29, 2012, which contains further discussions of the reserve estimates and evaluations prepared by LRPC as well as the qualifications of LRPC’s technical personnel responsible for overseeing such estimates and evaluations, included as Exhibits 99.1 and 99.2 to our Form S-1 filed with the SEC on October 10, 2012.

Technologies Used in Preparation of Proved Reserves Estimates

All of the proved producing reserves attributable to producing wells and/or reservoirs were estimated by performance methods.  These performance methods used are limited to decline curve analysis which utilized extrapolations of historical production and pressure data available through April 30, 2012.  The data used in this analysis was obtained from public data sources and was considered sufficient for calculating producing reserves.  The proved undeveloped reserves were estimated by the analogy method.  The analogy method uses pertinent well data obtained from public data sources that were available through April 30, 2012.
 

Oil and gas reserves and the estimates of the present value of future net revenues were determined based on prices and costs as prescribed by SEC and FASB guidelines.  Reserve calculations involve the estimate of future net recoverable reserves of oil and gas and the timing and amount of future net revenues to be received.  Such estimates are not precise and are based on assumptions regarding a variety of factors, many of which are variable and uncertain.  Proved oil and gas reserves are the estimated quantities of oil and gas that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions.  Proved developed oil and gas reserves are those expected to be recovered through existing wells with existing equipment and operating methods.  Proved reserves were estimated in accordance with guidelines established by the SEC and FASB, which require that reserves estimates be prepared under existing economic and operating conditions with no provision for price and cost escalations except by contractual arrangements.
 
Oil and Gas Production, Production Prices and Production Costs
 
The following table sets forth summary information regarding oil gas production, average sales prices and average production costs for 2012. We determined the Boe using the ratio of six Mcf of natural gas to one Boe. The ratios of six Mcf of natural gas to one Boe does not assume price equivalency and, given price differentials, the price for a Boe for natural gas may differ significantly from the price for a barrel of oil.
 
   
Year Ended
April 30, 2012
 
 Production
     
 Oil (Bbls)
   
9,792
 
 Gas (Mcf)
   
51,036
 
 Total (Boe)
   
18,298
 
 Total (Boe/d)
   
50
 
 Average prices
       
 Oil (per Bbl)
 
$
77.49
 
 Gas (per Mcf)
   
3.59
 
 Total (per Boe)
 
$
51.49
 
 Production Costs per BOE
 
$
4.41
 

Drilling Activity
 
The following table sets forth information on our drilling activity for the last year. The information should not be considered indicative of future performance, nor should it be assumed that there is necessarily any correlation between the number of productive wells drilled, quantities of reserves found or economic value.

   
Gross
   
Net
 
Exploratory Wells:
           
Productive
   
21.00
     
0.19
 
Dry
   
1.00
     
0.01
 
Total
   
22.00
     
0.20
 
 
Of the 22 gross (.20 net) wells drilled in 2012, all were completed as of April 30, 2012.
 
Although a well may be classified as productive upon completion, future changes in oil and gas prices, operating costs and production may result in the well becoming uneconomical.
 
Drilling Activity — Current
 
As of the date of this report, two wells are currently being drilled; one by CML and one by Chesapeake.  As a non-operator, we are we are unaware of drilling activity until we receive an AFE.
 
Delivery Commitments
 
We are not committed to provide a fixed and determinable quantity of oil, NGLs, or gas in the near future under existing agreements.
 
 
Producing Wells
 
The following table sets forth the number of producing wells in which we owned a working interest at April 30, 2012. Wells are classified as natural gas or oil according to their predominant production stream.
 
   
Gross
   
Net
 
Oil
   
49.00
     
0.70
 
Gas
   
7.00
     
0.13
 
Total
   
56.00
     
0.83
 

Acreage

The following table summarizes our developed and undeveloped acreage as of April 30, 2012.
 
   
Developed Acres
   
Undeveloped Acres
   
Total Acres
 
   
Gross
   
Net
   
Gross
   
Net
   
Gross
   
Net
 
 JHE
   
19,371
     
131
     
46,023
     
69
     
65,394
     
200
 
 Redfish Prospect
   
1,280
     
41
     
-
     
-
     
1,280
     
41
 
 Total
   
20,651
     
172
     
46,023
     
69
     
66,674
     
241
 
 
Undeveloped Acreage Expirations
 
As of April 30, 2012 all of our acreage was held by production (“HBP”) and not subject to expiration.

LEGAL PROCEEDINGS
 
Other than as listed below, we know of no material, active, or pending legal proceeding against our company, nor are we involved as a plaintiff in any material proceeding or pending litigation there such claim or action involves damages for more than 10% of our current assets. There are no proceedings in which any of our company’s directors, officers, or affiliates, or any registered or beneficial shareholders, is an adverse party or has a material interest adverse to our company’s interest.

Landers

On June 16, 2011, we acquired all of the outstanding equity interest in JHE Holdings, LLC. JHE Holdings, LLC was party to a litigation related to a mineral interest in the well known as Landers #1 (“Landers #1”) that was initiated in November 2008 in the District Court 82nd Judicial District, Robertson County, Texas. The litigation involved a multi-party trespass to try title suit to determine the ownership of Landers #1. Ross L. Martella III originally sought a temporary restraining order, but the lawsuit evolved into a trespass to try title action under Chapter 22 of the Texas Property Code. A Final Judgment was rendered in the suit in November, 2010 and it became final and non-appealable in December, 2010. Subsequently, two additional litigation matters involving Landers #1 were initiated. As of June 10, 2011, one of the suits was dismissed and Orbis Energy, Ltd. has agreed to indemnify JHE Holdings, LLC in connection with the remaining litigation related to Landers #1.

The parties consider the lawsuits to be a nuisance and we do not believe the Landers #1 litigation to be material due to Orbis Energy, Ltd’s agreement to indemnify us, hold harmless and defend us and our respective successors and assigns from any and all claims and/or costs associated with these lawsuits or any other claim which might be made against the interests that are subject to such litigation, at Orbis Energy, Ltd’s sole cost and expenses.

The property that is subject to the litigation was assigned to Orbis Energy, Ltd. on June 12, 2012 pursuant to the Note Payment Agreement.

In December 2012, a dismissal without prejudice judgment related to the Landers #1 litigation was executed.
 

Cottonwood

On or about June 18, 2012, our registered agent was served with a complaint (Civil Action No. 12-CV-327-CVE-PJC) filed in the United States District Court for the Northern District of Oklahoma by Cottonwood Natural Resources, Ltd. (“Cottonwood”).  Cottonwood alleges breach of contract and fraud in connection with a Purchase and Sale Agreement dated April 19, 2012 between us and Cottonwood (the “Cottonwood Purchase Agreement”) related to the purchase of certain oil and gas interests in approximately 14,640 acres in Finney County, Kansas (the “Finney Property”).  Cottonwood filed the complaint after we terminated the Cottonwood Purchase Agreement after we determined that Cottonwood had options to title to less than 12,908.46 net acres and Cottonwood failed to disclose all material facts related to the Finney Property. Cottonwood is seeking damages of at least $4,324,180. We believe that the allegations by Cottonwood are without merit and we intend to vigorously defend against the claims.  We are evaluating potential counterclaims against Cottonwood.

Greene Litigation
 
On June 19, 2012, we filed a petition with the District Court of Clark County, Kansas, Sixteenth Judicial District (Case No. 2012-CV-12) against Green Brothers Land Company, LLC, Greene Ranch Enterprises, Inc., David M. Greene, Jr., Marcia Greene, Thomas E. Greene, Janice C. Greene, Joseph B. Greene and Billie Greene (collectively the “ Greene Defendants”), requesting the return of a deposit pursuant to the termination of a certain Land Real Estate Sales Contract (the “Greene Agreement”) entered into between ourselves and the Greene Defendants on March 6, 2012, pursuant to which we would have acquired from the Greene Defendants certain interests in 6,518 acres of land in Kansas. Pursuant to the Greene Agreement, we delivered a $50,000 deposit that was refundable due a default by the sellers. We terminated the Green Agreement as a result of defects in title which the Greene Defendants did not cure within the time period set forth in the Greene Agreement. Prior to the litigation, we pursued an out of court settlement but was unsuccessful.

On November 13, 2012, the Company and the Greene Defendants entered into a Settlement Agreement and Release, whereby the parties agreed to split the Greene Deposit, $32,500 of which was to be delivered to the Company and $17,500 was to be delivered to the Greene Defendants, less any fees charged by the holder of the escrow account. On release of the funds from escrow, the parties agreed to dismiss the lawsuit and release each other from any future claims.
 
MANAGEMENT, CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS,
 
Arrangements between Directors and Officers
 
Other than the transactions discussed below, we have not entered into any transaction nor are there any proposed transactions in which any of our Directors, executive officers, stockholders or any member of the immediate family of any of the foregoing had or is to have a direct or indirect material interest.

On June 16, 2011, we completed the acquisition of JHE Holdings, LLC in accordance with terms of the JHE Purchase Agreement. Pursuant to the JHE Purchase Agreement, we acquired, effective on the June 1, 2011, all of the membership interests in JHE Holdings, LLC and accordingly, JHE Holdings, LLC became our wholly-owned subsidiary.  JHE Holdings, LLC was wholly owned by Mr. Johnson who was elected to our Board of Directors, subsequent to our acquisition of JHE Holdings, LLC, on June 16, 2011.  Mr. Johnson was appointed as Chairman of our Board of Directors on July 6, 2011 and appointed as Chief Executive Officer on October 11, 2011. As part of our acquisition of JHE Holdings, LLC, High Plains Oil, LLC, which was wholly owned by Mr. Johnson was issued 1,000,000 shares of our common stock and we paid the $1,000,000 installment payment due June 1, 2011, under a promissory note in the aggregate amount of $7,500,000 issued by High Plains Oil, LLC to James H. Edsel, Nancy Edsel, and James H. Edsel, Jr. in connection with the High Plains Acquisition. We were at arms’ length with Mr. Johnson prior to his appointment as a director.
 
On July 6, 2011, Mr. Brow, one of our directors, was granted an option to purchase 100,000 shares of our common stock under our stock option plan at an exercise price of $0.50 per share, which stock option was fully-vested on the date of grant. These stock options granted to Mr. Brow have expired.
 
In addition, as part of our acquisition of JHE Holdings, LLC, we were required to pay of Pimuro Capital Partners, LLC, a consultant who advised High Plains Oil, LLC with regards to the High Plains Acquisition and the JHE Purchase Agreement, the fees, commissions, and expenses  in the amount of $240,000 relating to such consulting arrangement between High Plains Oil, LLC and of Pimuro Capital Partners, LLC under the terms of an Installment Agreement, payable of $100,000 on the closing date and thereafter in monthly installments of $50,000, $50,000, and $40,000 commencing when JHE Holdings, LLC receives $75,000 in monthly aggregate distribution from JHE Holdings, LLC’s oil and gas properties. To date these fees have all been paid. Mr. Pina, our current Chief Financial Officer, is a former managing director of Pimuro Capital Partners, LLC. Mr. Pina was appointed as our Chief Financial Officer on July 11, 2011. We were at arms’ length with Mr. Pina prior to his appointment as Chief Financial Officer.  See section entitled “Executive Compensation.”
 
 
On October 11, 2011, Mr. Johnson was appointed as our Chief Executive Officer. Mr. Johnson was our Chairman of the Board when he was appointed as our Chief Executive Officer. See the section entitled “Executive Compensation.” below for more details of our employment agreement with Mr. Johnson.
 
In March 2012, we granted 150,000 shares of our common stock to each of our independent directors, which vest one year after the grant date. See section entitled “Director Compensation” below.

In June 2012, we conveyed to the Edsels, certain properties held by JHE Holdings, LLC as part of the Note Payment Agreement we entered into with the Edsels.  Pursuant to the Retained Profits Interest, High Plains Oil, LLC, an entity wholly owned by our Chairman and CEO, was entitled to 10% of the proceeds of the transaction and we paid High Plains Oil, LLC $25,000.

In July 2012, we granted 150,000 shares of common stock to Reed, an independent director, which vest one year after the grant date. See section entitled “Director Compensation” below.
 
Legal Proceedings, Cease Trade Orders and Bankruptcy
 
As of the date of this prospectus, no director or executive officer and no shareholder holding more than 5% of any class of our voting securities, or any associate of any such director, officer or shareholder is a party adverse to us or any of our subsidiaries or has an interest adverse to us or any of our subsidiaries.
 
No director or executive officer of our company is, as at the date of this prospectus, or was within 10 years before the date of this prospectus, a director, chief executive officer or chief financial officer of any company (including us), that:
 
 
(a)
was subject to a cease trade order, an order similar to a cease trade order or an order that denied the relevant company access to any exemption under securities legislation, for a period of more than 30 consecutive days, that was issued while the director or executive officer was acting in the capacity as director, chief executive officer or chief financial officer; or
 
 
(b)
was subject to a cease trade order, an order similar to a cease trade order or an order that denied the relevant company access to any exemption under securities legislation, for a period of more than 30 consecutive days, that was issued after the director or executive officer ceased to be a director, chief executive officer or chief financial officer and which resulted from an event that occurred while that person was acting in the capacity as director, chief executive officer or chief financial officer.
 
No director or executive officer of our company, and no shareholder holding a sufficient number of securities of our company to affect materially the control of our company:
 
 
(a)
is, as at the date of this prospectus, or has been within the 10 years before the date of this prospectus, a director or executive officer of any company (including us) that, while that person was acting in that capacity, or within a year of that person ceasing to act in that capacity, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold its assets;
 
 
(b)
has, within 10 years before the date of this prospectus, become bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency, or become subject to or instituted any proceedings, arrangement or compromise with creditors, or had a receiver, receiver manager or trustee appointed to hold the assets of the director, executive officer or shareholder;
 
 
(c)
has, within 10 years before the date of this prospectus, been the subject of, or a party to, any U.S. federal or state judicial or administrative order, judgment, decree, or finding, not subsequently reversed, suspended or vacated, relating to an alleged violation of:  (i) any U.S. federal or state securities or commodities law or regulation; or (ii) any law or regulation respecting financial institutions or insurance companies including, but not limited to, a temporary or permanent injunction, order of disgorgement or restitution, civil money penalty or temporary or permanent cease-and-desist order, or removal or prohibition order; or (iii) any law or regulation prohibiting mail or wire fraud or fraud in connection with any business entity; or
 
 
(d)
has, within 10 years before the date of this prospectus, been the subject of, or a party to, any sanction or order, not subsequently reversed, suspended or vacated, of any self-regulatory organization (as defined in Section 3(a)(26) of the United States Securities Exchange Act of 1934, as amended (the “Exchange Act”) (15 U.S.C.78c(a)(26))), any registered entity (as defined in Section 1(a)(29) of the Commodity Exchange Act (7 U.S.C.1(a)(29))), or any equivalent exchange, association, entity or organization that has disciplinary authority over its members or persons associated with a member.
 
 
No director or executive officer of our company, and no shareholder holding a sufficient number of our securities to affect materially the control of us has been subject to:
 
 
(a)
any penalties or sanctions imposed by a court relating to securities legislation or by a securities regulatory authority or has entered into a settlement agreement with a securities regulatory authority; or
 
 
(b)
any other penalties or sanctions imposed by a court or regulatory body that would likely be considered important to a reasonable investor in making an investment decision.
 
EXECUTIVE COMPENSATION
 
Employment Agreements

G. Jonathan Pina

On July 11, 2011, we entered into an employment agreement with Mr. Pina, pursuant to which Mr. Pina will serve as our Chief Financial Officer effective as of July 11, 2011. Pursuant to the terms of the employment agreement, Mr. Pina will receive an initial annual base salary of $180,000, which may be increased at the discretion of our Board of Directors, and Mr. Pina will also receive a signing bonus of 1,500,000 shares of our common stock, of which 500,000 shares of our common vest and were payable on execution of the employment agreement, 500,000 shares of our common stock vest and were payable on July 11, 2012 and 500,000 shares of our common stock vest and are payable on July 11, 2013. The term of the employment agreement is for two years and shall be automatically extended by one year unless notice is given 30 days prior to the expiration of the employment period or the agreement is otherwise terminated.

Mr. Pina’s employment agreement provides that in the event of Mr. Pina’s termination for any reason other than for Cause (as defined in Mr. Pina’s employment agreement) or a resignation for  Good Reason (as defined in Mr. Pina’s employment agreement), Mr. Pina will be entitled to severance payments (i) if the termination is after six months of employment, but less then twelve months, we shall pay severance, based upon Mr. Pina’s base salary and medical and dental insurance, if any, equal to six months' salary and reimburse Mr. Pina for medical and dental insurance as we are then obligated to pay, if any, for a period of six months, or (ii), if the termination is after twelve months or more of employment, we shall pay severance, based upon Mr. Pina’s base salary and medical and dental insurance, if any, equal to twelve months salary and reimburse Mr. Pina for medical and dental insurance as we are then obligated to pay, if any, for a period of twelve months.

In connection with Mr. Pina’s employment agreement, Mr. Pina was granted stock options under our stock option plan, consisting of options to purchase up to an aggregate of 350,000 shares of our common stock with 116,666 stock options vesting on July 11, 2012, 116,667 stock options vesting on July 11, 2013 and 116,667 stock options vesting on July 11, 2014. The exercise price for the stock options is $0.50, which is based upon the current price at which our shares of common stock was trading on the OTCBB, the lack of an active trading market of the common stock and the exploratory stage of our business.

On December 21, 2011, we entered into an amending agreement with Pina to amend his employment agreement. The amending agreement modifies the vesting of the shares of common stock Mr. Pina will received under his employment agreement, whereby Mr. Pina would receive 1,000,000 shares of our common stock on July 11, 2012 and 500,000 shares of our common stock on July 11, 2013. We rescinded and cancelled the original issuance of the 500,000 shares of our common stock issued to Mr. Pina on July 11, 2011.

The foregoing description of the Mr. Pina’s employment agreement and amending agreement are qualified in their entirety by reference to copies of such documents included as Exhibits 10.9 and 10.14 to our Form S-1 filed with the SEC on October 10, 2012.
 
S. Jeffrey Johnson
 
On October 11, 2011, we entered into an employment agreement with Mr. Johnson, our director and Chairman of the Board. Pursuant to the Mr. Johnson’s employment agreement, Mr. Johnson was appointed as our Chief Executive Officer. The term of Mr. Johnson’s employment agreement is for a two-year period beginning on October 1, 2011 and ending October 1, 2013. Under the terms of Mr. Johnson’s employment agreement, Mr. Johnson shall be paid a salary of not less than $200,000, annually. We agreed to an incentive stock compensation arrangement with Mr. Johnson that is anticipated to be linked to our success and increase shareholder value. Under the terms of the equity compensation, Mr. Johnson will be issued shares of our common stock (each, a “Restricted Share”), upon satisfaction of the following performance based conditions:
 
 
 
(a)
Restricted Share Issuance 1: 1,514,500 Restricted Shares are payable and issued on the following schedule so long as Mr. Johnson is employed or Mr. Johnson’s employment agreement is still effective: 1/3 on March 1, 2012, 1/3 on June 1, 2012, 1/3 on September 1, 2012 (as amended on February 29, 2012 to 1/3 on March 1, 2013, 1/3 on June 1, 2013, and 1/3 on September 1, 2013);
 
 
(b)
Restricted Share Issuance 2: 1,514,500 Restricted Shares are payable and issued after satisfaction of the following conditions:
 
 
(1)
Our daily trading volume exceeds 300,000 for 20 of the last 30 days prior to issuance; and
 
 
(2)
Our EBITDA (as defined in Mr. Johnson’s employment agreement) exceeds $4,000,000 during any four consecutive quarter periods during the term of Mr. Johnson’s employment agreement;
 
 
(c)
Restricted Share Issuance 3: 3,029,000 Restricted Shares are payable and issued after satisfaction of the following conditions:
 
 
(1)
Our daily trading volume exceeds 450,000  for 20 of the last 30 days prior to issuance; and
 
 
(2)
Our EBITDA exceeds $6,000,000 during any four consecutive quarter periods during the term of Mr. Johnson’s employment agreement;
 
 
(d)
Restricted Share Issuance 4: 3,029,000 Restricted Shares are payable and issued after we enter into a single Transaction (as defined in Mr. Johnson’s employment agreement) which has a Transaction Value (as defined in Mr. Johnson’s employment agreement) equal to or in excess of $100,000,000.

Under the terms of Mr. Johnson’s employment agreement, Mr. Johnson’s employment may be terminated with or without cause by us or by Mr. Johnson with 30 days written notice. If we terminate Mr. Johnson’s employment agreement, Mr. Johnson will be entitled to earn the Restricted Shares for a period of twelve months following such termination. If Mr. Johnson terminates his employment agreement, Mr. Johnson shall forfeit any unvested Restricted Shares, except the Restricted Shares issuable under Restricted Share Issuance 1.

The foregoing descriptions of Mr. Johnson’s employment agreement and amending agreement are qualified in their entirety by reference to the copies of such documents which are included as Exhibits 10.12 and 10.6 to our Form S-1 filed with the SEC on October 10, 2012.
 
 
The following table sets forth the cash compensation paid to our executive officers for services rendered until April 30, 2012.
 
Summary Compensation Table
 
Name and
Principal
Position
 
Year
 
Salary
($)
 
Bonus
($)
 
Stock
Awards
($)
 
Option
Awards
($)
 
Non-equity
deferred
compensation
earnings
($)
 
All other
Compensation
($)
 
Total
($)
 
Mr. Felipe A. Pati (i)
Former, President,  Treasurer Secretary and Director
   
2010
2011
2012
 
Nil
Nil
Nil
 
Nil
Nil
Nil
 
Nil
Nil
Nil
 
Nil
Nil
Nil
 
Nil
Nil
Nil
 
Nil
Nil
Nil
 
Nil
Nil
Nil
 
                                     
Mr. David Brow (ii)
Former President, Secretary, Treasurer and Director
   
2012
 
Nil
 
Nil
 
Nil
   
143,000 (iv)
 
Nil
 
Nil
   
143,000
 
                                         
G. Jonathan Pina (iii)
Chief Financial Officer and Secretary
   
2012
 
140,323
 
Nil
 
2,915,000 (iv)
   
500,500 (iv)
 
Nil
 
Nil
   
3,558,823
 
                                         
S. Jeffrey Johnson
Chief Executive Officer, Chairman of the Board of Directors
   
2012
 
116,667
 
Nil
 
2,862,405 (iv)
 
Nil
 
Nil
       
2,981,072
 

(i) Mr. Pati resigned as President, Treasurer and Secretary, effective June 2, 2011. Pati did not stand for re-election as a director at the annual and special meeting of our shareholders held on June 6, 2011.

(ii) Mr. Brow was appointed, President, Treasurer and Secretary, effective June 2, 2011. Mr. Brow was elected as a director on June 6, 2011. Effective July 11, 2011, Mr. Pina took over the role as our Principal Financial Officer and affective December 16, 2011, Mr. Pina took over the role as Secretary.  Effective October 11, 2011, Mr. Johnson took over the role as our Chief Executive Officer. On March, 5, 2012, Mr. Brow resigned as one of our directors. See Option Grants below for more detail.
 
(iii) Mr. Pina was appointed as Chief Financial Officer, effective July 11, 2011. Mr. Pina receives an annual salary of $180,000 and received 500,000 shares of our common stock as a bonus on July 11, 2011. The shares issued on July 11, 2011 under Mr.  Pina’s employment agreement were later rescinded. Mr. Pina received 1,000,000 shares of common stock on July 16, 2012 and will receive 500,000 shares of common stock on July 11, 2013. See Option Grants and Employment Agreement below for more information.
 
(iv) See note 8 of our annual consolidated financial statements. The stock options granted to Mr. Brow have expired.
 

The information below is as of April 30, 2012.
 
   
Option awards
   
Stock awards
 
Name
 
Number of securities underlying unexercised options (#) exercisable
   
Number of securities underlying unexercised options (#) unexercisable
   
Equity incentive plan awards: Number of securities underlying unexercised unearned options(#)
   
Option exercise price($)
   
Option expiration date
   
Number of shares or units of stock that have not vested (#)
   
Market value of shares or units of stock that have not vested ($)
   
Equity incentive plan awards: Number of unearned shares, units or other rights that have not vested (#)
   
Equity incentive plan awards: Market or payout value of unearned shares, units or others rights that have not vested ($)
 
Mr. Felipe A. Pati
Former President, Secretary,
(Treasurer and Director)
   
-
     
-
     
-
     
-
     
-
     
-
     
-
     
-
     
-
 
David Brow President,
Secretary and Director
(Former Treasurer)
   
100,000
  (i)
   
-
     
-