UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

_____________

FORM 10-K

_____________ 

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

For the fiscal year ended December 31, 2013

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

For the transition period from _____________ to ______________

Commission File Number: 000-52419

HOLLOMAN ENERGY CORPORATION

(Exact name of registrant as specified in its charter)

Nevada	77-0643398
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)

333 North Sam Houston Parkway East, Suite 410, Houston, Texas, 77060

(Address of Issuer's Principal Executive Offices, Zip Code)

Issuer’s telephone number, including area code:  (281) 260-0193

———————

Securities registered under section 12(g) of the Exchange Act: Common Stock, ($0.001 Par Value)

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes o  No þ

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

Indicate by check mark whether the registrant (1) filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act during the past 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes þ   No o

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

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (229.405 of this chapter) is not contained herein, and will not be contained, to the best of the registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. o

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

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

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

The aggregate market value of the voting and non-voting common equity held by non-affiliates computed by reference to the price at which the common equity was last sold on June 30, 2013 was $33,097,816.

As of March 28, 2014 the Company had 110,433,321 outstanding shares of common stock.

PART I

ITEM 1. BUSINESS.

Cautionary Statement Concerning Forward-Looking Statements

This report contains "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. These statements are subject to risks and uncertainties and are based on the beliefs and assumptions of management and information currently available to management. The use of words such as "believes," "expects," "anticipates," "intends," "plans," "estimates," "should," "likely" or similar expressions, indicates a forward-looking statement.

Forward-looking statements are not guarantees of performance. They involve risks, uncertainties and assumptions. Future results may differ materially from those expressed in the forward-looking statements. Many of the factors that will determine these results are beyond our ability to control or predict. Do not place undue reliance on any forward-looking statements. They speak only to the date made. For those statements, we claim the protection of the safe harbor for forward-looking statements contained in the Private Securities Litigation Reform Act of 1995.

Factors that could cause actual results to differ materially from those expressed or implied by such forward-looking statements include, but are not limited to:

● the success or failure of our joint venture partners with respect to their contract obligations to us; the impact of weather related delays and flooding on our exploration plans;

● the impact of economic recessions and changes in consumer and business consumption habits, including fluctuations in the price of oil and gas;  

● our ability to finance our business plan;

● our ability to deal effectively with competition and manage our growth;

● the success or commercial viability of our exploration and drilling plans;

● our ability to effectively judge acquisition opportunities and integrate acquired assets.

We operate in a very competitive and rapidly changing environment. New risks emerge from time to time and it is not possible for our management to predict all risks, nor can we assess the impact of all risks on our business or the extent to which any risk, or combination of risks, may cause actual results to differ from those contained in any forward-looking statements. All forward-looking statements included in this filing are based on information available to us on the date of the filing. Except to the extent required by applicable laws or rules, we undertake no obligation to publicly update or revise any forward-looking statement, whether as a result of new information, future events or otherwise. All subsequent written and oral forward-looking statements attributable to us or persons acting on our behalf are expressly qualified in their entirety by the cautionary statements contained throughout this filing.

Business

General

We were incorporated on May 14, 2004 in Nevada. Between May 2004 and May 2007 we were relatively inactive. In May 2007, we directed our focus to the acquisition, exploration, and development of oil and gas properties. We are currently controlled by Holloman Corporation, a Texas corporation involved in the engineering and construction of pipelines and mid-stream gas processing facilities.

All of our exploration and development efforts are concentrated in Australia. We hold working interests in petroleum exploration licenses covering 3,444 square kilometers (851,030 gross acres, 412,755 net acres) located on the western flank of Australia’s Cooper Basin.

Effective May 11, 2012, we entered into a definitive Oil and Gas Farm-In Agreement with Terra Nova Energy Ltd., and its wholly owned subsidiary Terra Nova Resources Inc. (“Terra Nova”), which provides Terra Nova the right to earn up to a 55% undivided working interest in our Australian licenses in exchange for undertaking certain exploration obligations (the “Terra Nova Farm-In Agreement”).

We are an exploration stage company and did not participate in drilling any wells during the three years preceding June 30, 2013. On July 23, 2013, we spudded the Wolfman #1 exploration well on PEL 112. The Wolfman #1 did not encounter oil or gas and was plugged and abandoned.

As of March 28, 2014 we did not have any proven oil or gas reserves and we did not have any revenue.

2

Our Australian assets

In May 2007 we acquired a 62.5% working interest in an offshore Australian oil and gas exploration permit known as Victoria Permit 60 (“Vic P60”). We paid $639,487 in cash plus a 4.00% overriding royalty participation for this interest. On November 21, 2007 we acquired Holloman Petroleum Pty. Ltd. (“Holloman Petroleum”) for 18,600,000 shares of our common stock. Holloman Petroleum’s assets consisted of working interests, varying between 37.5% and 100%, in seven oil and gas permits awarded by the Australian Government. These permits, one of which included the remaining 37.5% working interest in Vic P60, covered 8,087 square kilometers (1,998,348 acres) of land in the Cooper/Eromanga Basin and 2,589 square kilometers (639,755 acres) offshore in the Gippsland Basin and the Barrow Sub-Basin. We have subsequently relinquished the Vic P60 and Barrow Sub-Basin permits and consolidated two of our onshore licenses.

Onshore licenses – Cooper Basin

We currently hold working interests of 48.5007% in two onshore Petroleum Exploration Licenses (PELs) in Australia. PEL 112 is comprised of 1,086 square kilometers (268,356 gross acres). PEL 444 is comprised of 2,358 square kilometers (582,674 gross acres). Both licenses are located on the southwestern flank of the Cooper Basin in the State of South Australia. We are obligated to pay 3.53% in royalties on our revenues generated by operations on these licenses.

The Department of Primary Industries and Resources of South Australia reports that the Cooper Basin has sourced over 158 million barrels of oil, 5 trillion cubic feet of gas and 155 million equivalent barrels of LPG and condensate. It has in excess of 120,000 kilometers of 2-D seismic data and more than 1,970 wells in more than 103 oil and 165 gas fields. From January 2002 through to December 2012, 195 exploration wells and 85 appraisal/development wells have been drilled by the new explorers in the Cooper Basin. Most have targeted oil, however both oil and gas have been discovered. The new entrants found hydrocarbons in 89 of these wells (46% technical success rate) and 76 were cased and suspended as future producers (39% commercial success rate). Our management believes that Australia provides a stable regulatory, tax and business environment in the oil and gas sector.

Heavy rains beginning in February 2010 created wide scale flooding in the Cooper Basin. For nearly eighteen months, the inaccessibility of roads and facilities partially curtailed Cooper Basin oil production and resulted in a general contraction of exploration activity. As a result, we have applied for, and have been granted multiple license extensions on PEL 112 and PEL 444 from the Government of South Australia. Effective January 9, 2012, we were granted a variation of license terms on PEL 112. Under the variation, the minimum work requirements for PEL 112 License Year Three (3) were exchanged for those of PEL 112 License Year Four (4). Accordingly, the timeframe for acquisition of 100 kilometers of 2D seismic data on that license was moved from January 10, 2012 to January 10, 2013. Our seismic obligation on PEL 112 was completed in late September 2012. During January 3, 2013, we were also granted a six-month extension on PEL 444 such that the timeframe for acquisition of 200 kilometers of 2D seismic data on that license was moved from January 10, 2013 to July 11, 2013, and the overall license term for PEL 444 was extended to July 11, 2015. Seismic acquisition on PEL 444  was completed in July 2013.

Under Australian law, at the end of each five year term, one third of the area covered by a petroleum exploration license must be relinquished. In June 2008 the Government of South Australia renewed the lease term and associated work programs for PEL 112 and PEL 444 by five years. In connection with that renewal, we identified and relinquished one-third of the acreage covered by PEL 112 and PEL 444.

During November 2013, we applied for our final five-year renewal of PEL 112. On December 18, 2013, the Government of South Australia accepted our application and offered to renew PEL 112 in accordance with our suggested terms. In connection with that renewal, we identified and relinquished one-third of the acreage covered by PEL 112. The remaining license acreage contains all areas over which 2D and 3D seismic has been acquired, and all existing leads and prospects. We believe the acreage we relinquished was non-prospective. On March 12, 2014, the Government of South Australia finalized its renewal of PEL 112. As a result, we now hold a 48.5007% working interest in PEL 112 (which is comprised of 1,086 square kilometers (268,356 acres) until January 10, 2019.

To maintain our exploration rights in the Cooper/Eromanga Basin, the Australian Government requires that we fulfill the following minimum work commitments:

License	Description of Minimum Work Obligation	Date of Required Completion
PEL 444	Geological and geophysical studies	July 11, 2014
PEL 444	Drill one well	July 11, 2015
PEL 112	Geological and geophysical studies	January 10, 2015
PEL 112	Geological and geophysical studies	January 10, 2016
PEL 112	Acquire 50 square kilometers – 3D seismic	January 10, 2017
PEL 112	Geological and geophysical studies	January 10, 2018
PEL 112	Drill one well	January 10, 2019

The farm-in agreement through which we hold our working interests in PEL 112 and PEL 444 also obligates us to fulfill the drilling commitment set forth in the licenses. Under Australian law, we are entitled to apply for one additional 5-year term on PEL 444.

3

Our oil and gas farm-in agreements and exploration activity

Cooper Basin farm-in agreements

Effective May 11, 2012, we entered the Terra Nova Farm-In Agreement with Terra Nova, Australian-Canadian Oil Royalties Ltd. (“ACOR”) and Eli Sakhai (“Sakhai”) on PELs 112 and 444. The Terra Nova Farm-In Agreement provides terms under which Terra Nova may earn a 55% undivided working interest in PEL 112 and PEL 444 (the “Farm-In Interest”).

To earn the entire Farm-In Interest, Terra Nova is required to fund exploration and development expenditures (the “Earning Obligations”) totaling at least AUD$13,700,000 (USD$13,702,000) including:

● AUD$4,700,000 (USD$4,968,000) which was placed in escrow during May 2012, for use in the completion of a seismic acquisition program sufficient to meet the minimum seismic acquisition requirements and interpretation of the acquired data for PEL 112 and PEL 444 (earning a 20% working interest in each license); and  

● AUD$4,500,000 (USD$4,670,000) which was placed in escrow on November 1, 2012 to secure Terra Nova’s obligation to sole fund the dry-hole costs of an initial three (3) well drilling program on either PEL 112 or PEL 444, provided that at least one well is drilled on each license (earning a working interest of 5.833% per well in each license, totaling a working interest of 17.5%); and  

● AUD$4,500,000 (USD$4,064,000) to be placed in escrow on or before 45 days following completion or abandonment of the third well in the initial well program for use in funding the first AUD$4,500,000 in dry-hole costs of an optional three (3) well drilling program on either PEL 112 or PEL 444, provided that at least one well is drilled on each license (earning a working interest of 5.833% per well in each license, totaling a working interest of 17.5%).

Terra Nova will act as contract operator with respect to all seismic acquisition and drilling work contemplated by the Terra Nova Farm-In Agreement.

Effective May 29, 2013, the Terra Nova Farm-In Agreement was amended such that of the AUD$4,500,000 (USD$4,670,000) placed in escrow for the Initial Well Program, AUD$500,000 (USD$482,250) was used to pay costs incurred in the PEL 444 seismic program. Costs incurred in relation to the seismic earning obligations in excess of AUD$5,200,000 (USD$5,152,000) are borne by Terra Nova, ACOR, Sakhai and us in accordance with our/their working interest percentages calculated as though Terra Nova had successfully completed its Earning Obligations and earned the entire Farm-In Interest.

In the event Terra Nova elects to complete the second well drilled in connection with the initial three well drilling program, Terra Nova shall pay 50% of the completion cost and we will pay the other 50% of the completion costs. In the event Terra Nova elects to complete the third well drilled in connection with the initial three well drilling program, or any well drilled in connection with the optional three well drilling program, Terra Nova shall pay 50% of the completion cost, and we, ACOR and Sakhai shall pay the other 50% of the completion costs in accordance with our working interest at the effective date of the Terra Nova Farm-In Agreement.

In the event any well drilled in connection with either the initial or optional drilling programs is commercially viable, and Terra Nova elects to complete such well, Terra Nova is entitled to a preferential recovery of one hundred percent of the costs it has paid to drill and test that successful well. Terra Nova is entitled to 80% of production from that successful well until either that successful well has ceased production or Terra Nova has received net revenue equal to the reimbursable costs it has incurred.

Terra Nova earns the Farm-In Interest in stages based upon successful completion of specific Earning Obligations. In each instance, we, ACOR and Sakhai will each contribute a portion of the working interest earned by Terra Nova. In the event Terra Nova earns the entire Farm-In Interest, we, ACOR and Sakhai will transfer to Terra Nova the following working interest percentages in both PEL 112 and PEL 444:

(a)	We will contribute an undivided 38.556% working interest in both PEL 112 and PEL 444 (resulting in a residual working interest position of 28.112% in each license);
(b)	ACOR will contribute an undivided 8.222% working interest in both PEL 112 and PEL 444; and
(c)	Sakhai will contribute an undivided 8.222% working interest in both PEL 112 and PEL 444.

The Terra Nova Farm-In Agreement may be terminated by any party upon the occurrence of an uncured breach of any material term. Terra Nova may terminate the Agreement any time before it has earned the Farm-In Interest upon providing written notice of such termination. In the event Terra Nova terminates the Agreement, it shall not be entitled to any interest in either PEL 112 or PEL 444 unless it has satisfied an Earning Obligation with respect to that license.

On February 27, 2012, we terminated a previous farm-in agreement on PEL 112 and PEL 444 with Brandenburg Energy Corp. ("Brandenburg"). Brandenburg’s contract rights were subject to meeting certain milestones including an obligation to pay us AUD$7,400,000 (USD$7,822,000) on or before September 20, 2011. Brandenburg was unable to pay this amount.

4

Cooper Basin exploration activity

Our Cooper Basin exploration plan includes the acquisition of 3D seismic data on PEL 112 and PEL 444, and the drilling, completion and equipping of six (6) wells shared across both licenses. Current estimates indicate the costs to perform this work could be AUD$37.5 million (USD$33.9 million). Of this amount, approximately AUD$10.9 million (USD$9.8 million) has already been expended.

PEL 112

Acquisition of 127 square kilometers of 3D seismic data on PEL 112 (the “Mulka Survey”) was completed in late September 2012. The Mulka Survey fulfilled our minimum work requirements for PEL 112 License Year Four. Geokinetics (Australia) Pty. Ltd. undertook the Mulka Survey on the northern boundary of PEL 112 under the direction of Terra Nova. During February 2013, we received copies of the Mulka Survey data and interpretation from Terra Nova. As a result, Terra Nova completed its seismic Earning Obligation with respect to PEL 112, and earned an undivided 20% working interest in that license. We, ACOR and Sakhai each contributed the following portion of the working interest earned to Terra Nova:

(a)	We contributed an undivided 13.3334% working interest in PEL 112 resulting in a residual working interest position of 53.334% in that license;
(b)	ACOR contributed an undivided 3.3333% working interest in PEL 112; and
(c)	Sakhai contributed an undivided 3.3333% working interest in PEL 112.

On July 17, 2013, the Government of South Australia finalized and registered the transfer of the 20% working interest earned by Terra Nova in PEL 112.

Seven drilling targets were identified as a result of the final interpretation of the Mulka Survey data. We believe our primary drilling targets are similar geologically to producing structures observed in existing oil pools (including the Butlers, Perlubie and Parsons fields) located to the north of PEL 112 on the Cooper Basin’s western-flank. Seismic interpretation indicates that all primary targets display 4-way structural closures.

Work Area Clearance (“WAC”) on PEL 112 access roads and drill site locations began April 20, 2013 and was completed on April 22, 2013. WAC is the process by which anthropologists and representatives of Australia’s Native Title Holders review exploration sites to ensure planned activity does not harm the cultural integrity of the land to be explored.

On July 23, 2013, we spudded the Wolfman #1 exploration well on PEL 112. The well’s primary oil objective, the Namur Sandstone, was encountered at approximately 1,197 meters (3,927 feet) on August 6, 2013. Drilling continued to its secondary targets in the Birkhead formation and Hutton sandstones. Wolfman #1 reached Total Depth of 1,703 meters (5,587 feet), on August 7, 2013. No oil shows were observed in the primary and secondary oil objectives, and the well was plugged and abandoned. The entire cost of the well was paid by Terra Nova in accordance with the terms of the Terra Nova Farm-In Agreement.

The drilling of Wolfman #1 fulfilled our minimum work requirement for PEL 112 License Year Five. 3D Sesimic data has been acquired on only 11.7% (31,382 of 268,356 gross acres) of the land comprising PEL 112. We believe significant potential remains for future seismic to identify migration trends and additional prospects on PEL 112 during the next exploration term.

Upon completion of Wolfman #1 Terra Nova earned an additional undivided 5.8333% working interest in PEL 112. We, ACOR and Sakhai each contributed the following portion of the working interest earned to Terra Nova:

(a)	We contributed an undivided 4.8333% working interest in PEL 112 resulting in a residual working interest position of 48.5007% in that license;
(b)	ACOR contributed an undivided 0.5000% working interest in PEL 112; and
(c)	Sakhai contributed an undivided 0.5000% working interest in PEL 112.

On December 20, 2013, the Government of South Australia registered the transfer of the 5.8333% working interest earned by Terra Nova in PEL 112.

5

PEL 444

Acquisition of 80 square kilometers of 3D seismic data on PEL 444 (the “Wingman Survey”) began May 28, 2013 and was completed July 2, 2013. The Wingman Survey was conducted over a portion of PEL 444 that lies within the "Western Margin" of the Cooper Basin, which is generally considered highly prospective. This trend is being actively drilled by adjacent licensees including Senex Energy and Beach Energy.

During February 2014, Terra Nova finalized its interpretation of the Wingman Survey data and earned a 25.8333% working interest in PEL 444. The working interest earned by Terra Nova was comprised of a 20% interest resulting from the completion of the Wingman Survey and a 5.8333% interest granted in connection with Terra Nova’s completion of the Wolfman #1 well. The Company, ACOR and Sakhai each contributed a portion of the working interest earned by Terra Nova as follows:

(a)   The Company contributed an undivided 18.1667% working interest in PEL 444 resulting in a residual working interest position of 48.5007% in that license;

(b)   ACOR contributed an undivided 3.8333% working interest in PEL 444; and

(c)   Sakhai contributed an undivided 3.8333% working interest in PEL 444.

As of March 28, 2014 the Government of South Australia was processing the documents required to finalize the transfer of the working interest earned by Terra Nova.

Other

During 2011 and 2010, we completed processing of more than 666 km (414 miles) of 2D seismic data. This reprocessing covered a significant portion of PEL 112 and PEL 444. Our 2D seismic reprocessing was performed by Dayboro Geophysical Pty Ltd (“Dayboro”) under the supervision of Isis Petroleum Consultants Pty Ltd (“Isis”). Both Dayboro and Isis are independent engineers with lengthy geological and geophysical work experience in the Cooper Basin. The processing sequence targeted lines which complimented our technical assessment of likely drilling prospects and future seismic acquisition.

We have also completed a broad range of technical studies relating to PEL 112 and PEL 444. In largest part, the studies were performed by Isis and included; a) a review of Cooper Basin exploration acreage (including an analysis of the chronostratigraphy, an assessment of neighboring exploration results, an analysis of petroleum systems and a probabilistic volumetric assessment of leads), b) oil migration studies, c) adjacent oil pools studies, and d) economic feasibility studies. In the opinion of management, these studies increased the value of both licenses.

Competition

The petroleum and natural gas industry is highly competitive. Numerous independent oil and gas companies, oil and gas syndicates and major oil and gas companies actively seek out and bid for oil and gas properties as well as for the services of third party providers, such as drilling companies, upon which we rely. In the Cooper Basin, seismic and drilling contractors are limited. In large part, their schedules are controlled by demand from larger explorers in the area. Certain of our competitors control roads, bridges and other infrastructure we require to access our properties. Our reliance upon their infrastructure may create a competitive disadvantage for us. A substantial number of our competitors have longer operating histories and substantially greater financial and personnel resources than we do, and have demonstrated the ability to operate through industry cycles.

Some of our competitors not only explore for, produce and market petroleum and natural gas, but also carry out refining operations and market the resultant products on a worldwide basis which may provide them with additional sources of capital. Larger and better capitalized competitors may be in a position to outbid us for particular prospect rights. These competitors may also be better able to withstand sustained periods of unsuccessful drilling. Larger competitors may be able to absorb the burden of any changes in laws and regulations more easily than we can, which would adversely affect our competitive position.

Petroleum and natural gas producers also compete with other suppliers of energy and fuel to industrial, commercial and individual customers. Competitive conditions may be substantially affected by various forms of energy legislation and/or regulation considered from time to time by the governments and/or their agencies and other factors which are out of our control including, international political conditions, terrorism, overall levels of supply and demand for oil and gas, and the markets for synthetic fuels and alternative energy sources.

6

 Regulation

The exploration, production and sale of oil and gas are extensively regulated by governmental authorities. Applicable legislation is under constant review for amendment or expansion. These efforts frequently result in an increase in the regulatory burden on companies in our industry and consequently an increase in the cost of doing business and decrease in profitability. Numerous governmental departments and agencies are authorized to, and have, issued rules and regulations imposing additional burdens on the oil and gas industry that often are costly to comply with and carry substantial penalties for non-compliance. Production operations are affected by changing tax and other laws relating to the petroleum industry, constantly changing administrative regulations and possible interruptions or termination by government authorities.

Oil and gas mineral rights may be held by individuals, corporations or governments having jurisdiction over the area in which such mineral rights are located. As a general rule, parties holding such mineral rights grant licenses or leases to third parties to facilitate the exploration and development of these mineral rights. The terms of the leases and licenses are generally established to require timely development. Notwithstanding the ownership of mineral rights, the government of the jurisdiction in which mineral rights are located generally retains authority over the drilling and operation of oil and gas wells.

Environmental considerations

Our operations are also subject to a variety of constantly changing laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. Failure to comply with these laws and regulations can result in the imposition of substantial fines and penalties as well as potential orders suspending or terminating our rights to operate. Some environmental laws to which we are subject provide for strict liability for pollution damage, rendering a person liable for environmental damage without regard to negligence or fault on the part of such person. In addition, we may be subject to claims alleging personal injury or property damage as a result of alleged exposure to hazardous substances, such as oil and gas related products or for other reasons.

Some environmental protection laws and regulations may expose us to liability arising out of the conduct of operations or conditions caused by others, or for acts which were in compliance with all applicable laws at the time the acts were performed. Changes in environmental laws and regulations, or claims for damages to persons, property, natural resources or the environment, could result in substantial costs and liabilities to us. These laws and regulations may substantially increase the cost of exploring, developing, producing or processing oil and gas and may prevent or delay the commencement or continuation of a given project and thus generally could have a material adverse effect upon our capital expenditures, earnings, or competitive position. We believe that we are in substantial compliance with current applicable environmental laws and regulations. Nevertheless, changes in existing environmental laws and regulations or in the interpretations thereof could have a significant impact on us and the oil and gas industry in general.

Other

We currently have no full-time employees. We use consultants and contractors to provide us, among other things, with executive management and accounting services, and technical engineering support.

Other than seismic, engineering, geochemical and geophysical programs capitalized in connection with our oil and gas concessions, we have devoted no substantial efforts to research and development within the last two fiscal years.

Our offices are located at 333 North Sam Houston Parkway East, Suite 410, Houston, Texas 77060. Our offices are provided under the terms of an administrative services agreement with Holloman Corporation, the parent company of our controlling shareholder.

ITEM 1.A. RISK FACTORS.

Our failure to obtain capital may significantly restrict our proposed operations

We need additional capital to fund operating losses and to explore for oil and gas. If we are unable to access funding when needed on acceptable terms, we may not be able to fully implement our business plans, take advantage of business opportunities, respond to competitive pressures, or refinance our debt obligations as they come due, any of which could have a material adverse effect on our business, financial condition, cash flows, and results of operations.

We do not know the terms by which we may obtain any future capital, but any future sale of our equity securities would dilute the ownership of existing stockholders and could be at prices substantially below the market price of our common stock. We may not be able to obtain the capital we need.

7

We have never earned a profit from our oil and gas operations.

We expect to incur losses during the foreseeable future and we may never be profitable. To enable us to continue in business we will eventually need to earn a profit or obtain additional financing until we are able to earn a profit.

Oil and gas exploration is not an exact science, and involves a high degree of risk

Our primary exploration risk lies in the drilling of dry holes or drilling and completing wells which, though productive, do not produce gas and/or oil in sufficient amounts to return the amounts expended and produce a profit. Hazards, such as unusual or unexpected formation pressures, downhole fires, blowouts, loss of circulation of drilling fluids and other conditions are involved in drilling and completing oil and gas wells and, if such hazards are encountered, completion of any well may be substantially delayed or prevented. In addition, adverse weather conditions can hinder or delay operations, as can shortages of equipment and materials or unavailability of drilling, completion, and/or work-over rigs. Even though a well is completed and is found to be productive, water and/or other substances may be encountered in the well, which may impair or prevent production or marketing of oil or gas from the well. Exploratory drilling involves substantially greater economic risks than development drilling because the percentage of wells completed as producing wells is usually less than in development drilling. Exploratory drilling itself can generally be divided into higher risk attempts to discover a reservoir in a completely unproven area or relatively lower risk efforts in areas not too distant from existing reservoirs. While exploration adjacent to or near existing reservoirs may be more likely to result in the discovery of oil and gas than in completely unproven areas, exploratory efforts are nevertheless high risk activities.

Although the completion of oil and gas wells is, to a certain extent, less risky than drilling for oil and gas, the process of completing an oil or gas well is nevertheless associated with considerable risk. In addition, even if a well is completed as a producer, the well for a variety of reasons may not produce sufficient oil or gas in order to repay our investment in the well.

The acquisition, exploration and development of oil and gas properties and the production and sale of oil and gas are subject to many factors which are outside our control

These factors include, among others, general economic conditions, proximity to pipelines, oil import quotas, supply, demand, and price of other fuels and the regulation of production, refining, transportation, pricing, marketing and taxation by federal, state, and local governmental authorities.

Due to the distances and infrastructure limitations involved in Cooper Basin exploration, we are subject to the impact of rains and flooding. Our Cooper Basin properties are situated largely on desert terrain. Though flooding is rare, we have experienced significant delays resulting from land access restrictions due to high standing water. Flooding in the past has resulted in increased investment in roads, bridges and infrastructure targeted at minimizing the effect of future heavy rains.

The marketability of our production depends in part upon the availability, proximity, and capacity of pipelines, and processing facilities.  Any significant change in market factors affecting these infrastructure facilities, as well as delays in the construction of new infrastructure facilities, could harm our business.  Any oil that we may produce will be delivered using facilities that we do not own or operate.  As a result, we are subject to the risk that these facilities may be temporarily unavailable due to mechanical reasons or market conditions, or may not be available to us in the future.  If we experience interruptions that impact a substantial amount of our production, it could have a material adverse effect on our business, financial condition, cash flows, and results of operations.

The drilling of oil and gas wells involves hazards such as blowouts, unusual or unexpected formations, pressures or other conditions which could result in substantial losses or liabilities to third parties

Although we believe the coverage and types of insurance we maintain are currently adequate, we may not be insured against all losses because insurance may not be available, premium costs may be deemed unduly high, or for other reasons. Accordingly, uninsured liabilities could result in significant losses and have a material adverse effect on our operations.

The price of our common stock may become volatile, which could lead to losses by investors and costly securities litigation.

The trading price of our common stock is likely to be highly volatile and could fluctuate in response to factors such as:

●   actual or anticipated variations in our operating results;

●   announcements by us or our competitors of significant acquisitions, strategic partnerships, joint ventures, capital commitments, or other business developments, such as oil or gas discoveries;

●   adoption of new accounting standards affecting our industry;

●   additions or departures of key personnel;

●   sales of our common stock or other securities in the open market;

●   conditions or trends in our industry;

●   changes in business, legal or regulatory conditions, or other developments affecting the oil and gas industry; and

●   other events or factors, many of which are beyond our control.

8

The stock market has experienced significant price and volume fluctuations, and the market prices of stock in exploration stage companies have been highly volatile.  In the past, following periods of volatility in the market price of a company's securities, securities class action litigation has often been initiated against our company.  Litigation initiated against us, whether or not successful, could result in substantial costs and diversion of our management's attention and resources, which could harm our business and financial condition.

Also see Item 1 above for a discussion of our competitive, regulatory and environmental risks.

IN ADDITION TO THE RISK FACTORS SET FORTH ABOVE, WE ARE SUBJECT TO NUMEROUS OTHER RISKS SPECIFIC TO OUR COMMON STOCK, OUR PARTICULAR BUSINESS AS WELL AS GENERAL BUSINESS RISKS. INVESTORS ARE URGED TO CONSIDER ALL OF THE RISKS INHERENT IN OUR SECURITIES PRIOR TO PURCHASING OR MAKING AN INVESTMENT DECISION.

ITEM 2. PROPERTIES.

See Item 1 of this report.

ITEM 3. LEGAL PROCEEDINGS.

None

ITEM 4. MINE SAFETY DISCLOSURE

Not applicable.

9

PART II

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.

Our common stock trades on the OTCQB under the symbol “HENC.” The following chart shows the high and low bid prices as quoted by the OTC Bulletin Board or OTCQB Markets for each quarter for the fiscal years ended December 31, 2013 and 2012. Such prices represent quotations between dealers, without dealer markup, markdown or commissions, and may not represent actual transactions.

Quarter	High		Low
4th Quarter 2013	$	0.36	$	0.22
3rd Quarter 2013	$	0.67	$	0.23
2nd Quarter 2013	$	0.69	$	0.33
1st Quarter 2013	$	0.47	$	0.33
4th Quarter 2012	$	0.50	$	0.21
3rd Quarter 2012	$	0.35	$	0.18
2nd Quarter 2012	$	0.44	$	0.11
1st Quarter 2012	$	0.43	$	0.11

There is currently only a limited market for our common stock. A limited market is characterized by a relatively limited number of shares in the public float, relatively low trading volume and the small number of brokerage firms acting as market makers. The market for low priced securities is generally less liquid and more volatile than securities traded on national stock markets. Fluctuations in market prices are not uncommon. No assurance can be given that the market for our common stock will continue or that the stock price will be maintained.

As of March 28, 2014 we had 40 record holders of our common stock.

We have not declared any dividends and we do not plan to declare any dividends in the foreseeable future. We plan to retain earnings to finance the expansion of our operations.

On December 31, 2013, we issued 50,149 shares of our common stock, at an average price of $0.299 per share, in connection with the conversion of $15,000 in administrative service fees payable to a wholly owned subsidiary of our controlling shareholder, Holloman Corporation. The certificates representing the shares will bear a restricted legend providing that they cannot be sold unless pursuant to an effective registration statement or an exemption from registration. We relied upon the exemption provided by Section 4(2) of the Securities Act of 1933 in connection with the issuance of these shares and did not pay any underwriting discounts or sales commissions.

During the year ended December 31, 2013 we did not purchase any shares of our common stock from third parties in a private transaction or the open market. During the year ended December 31, 2013 none of our officers or directors, nor any of our principal shareholders, purchased any shares of our common stock on our behalf from third parties in a private transaction or as a result of purchases in the open market.

10

ITEM 6. SELECTED FINANCIAL DATA.

Not Applicable

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

Results of Operations

Our combined consulting, management and professional fees for the year ended December 31, 2013, decreased by approximately $484,000 or 63% (from $777,573 to $293,710) when compared to the prior fiscal year. This decrease relates almost entirely to issuances under our 2009 Stock Bonus Plan ($21,750) and one-time bonuses paid in stock (totaling $483,334) during May 2012 in connection with successful completion of the Terra Nova Farm-In Agreement. More specifically, on April 2, 2012, our Board of Directors consented to the distribution of 666,670 shares of the common stock of Terra Nova to our directors, officers and principal advisors. These shares were distributed as compensation for efforts put forth in securing the Terra Nova Farm-In Agreement. The 666,670 shares had an aggregate value of $193,334, or $0.29 per share. On April 2, 2012 we also granted 1,000,000 shares of our common stock to a consultant whose efforts we judged instrumental in identifying and finalizing the Terra Nova Farm-In Agreement. The grant was conditioned upon the execution of that agreement which occurred on May 11, 2012. The 1,000,000 bonus shares had a fair market value at the date of grant equal to $290,000, or $0.29 per share. In addition, our Chief Executive officer was granted 75,000 shares of our common stock (fair value $21,750), under the terms of our 2009 Stock Bonus Plan during April 2012. No such grants or issuances were made during the current year.

Our office and travel expenses remained relatively stable between 2013 and 2012.

During the years ended December 31, 2013 and 2012, we incurred interest expense of $44,650 and $740, respectively. This increase in interest relates almost entirely to financing costs incurred in connection a loan of $1,000,000 finalized in late December 2012 (see further details below).

The Australian dollar decreased from 1.037 to 0.887 US dollars during the year ended December 31, 2013 and increased from 1.020 to 1.037 US dollars during the year ended December 31, 2012. As a result, we recognized a foreign exchange gain of $746,669 during 2013 and a foreign exchange loss $98,491 during 2012. Substantially all of our non-cash foreign exchange losses relate to the measurement of US dollars required to settle deferred taxes payable to the Australian Government in connection with our acquisition of PEL 112 and PEL 444.

On April 3, 2012, we granted 1,800,000 stock options to our Chief Executive Officer pursuant to the 2009 Non-Qualified Stock Option Plan (See Note 8 to the financial statements which accompany this report for a more detailed discussion). We determined that the total fair market value of the options granted was $104,874. Since the options were entirely vested at the date of grant, we recognized the entire value of the options as stock-based compensation expense during the year ended December 31, 2012. We recognized no expense in connection with the option plan during the year ended December 31, 2013, since all compensation expense related to the plans had been previously recognized.

In connection with the Terra Nova Farm-In Agreement, Terra Nova paid us cash fees totaling $350,000, and 666,670 shares of its common stock with a fair market value of $193,334. All fees paid by Terra Nova were fully earned upon receipt, and were not repayable to Terra Nova under any circumstances. After an offset of $54,719 in amounts refunded to ACOR and Sakhai, we recognized other income relating to these fees of $488,615 during the year ended December 31, 2012. During the year ended December 31, 2013, we had no other income.

On an inception to date basis, we have recognized a net loss of approximately $14,947,000. In largest part, that loss consisted of non-cash expense including: stock-based fees and compensation expense of $3,339,000, unrealized foreign exchange loss of $214,000, and a net impairment of oil and gas properties of approximately $5,152,000. In addition, we have incurred a net loss of  $1,671,000 related to the discontinued operations of a former subsidiary, and approximately $4,571,000 in other net losses, related to exploration stage operations.

11

Financial Condition, Liquidity and Capital Resources

The execution of the Terra Nova Farm-In Agreement significantly enhanced our exploration capacity. On May 11, 2012, Terra Nova closed an equity financing for gross proceeds equal to CAD$10,652,000 (USD$10,663,000). During May 2012, Terra Nova placed AUD$4,700,000 (USD$4,968,000) in escrow for use in the completion of the Mulka and Wingman seismic surveys. During May 2013, we agreed to amend the Terra Nova Farm-In Agreement such that of the amount placed in escrow for the Initial Well Program, AUD$500,000 (USD$482,250) could be used to pay costs incurred on the Wingman Survey as well. During July 2013, we also paid a cash call to Terra Nova of AUD$523,259 (USD$475,747) covering our portion of the costs incurred on the Wingman Survey in excess of the funds escrowed in connection with those seismic efforts.

On November 1, 2012, Terra Nova deposited AUD$4,500,000 (USD$4,670,000) in escrow as a deposit to sole fund the dry-hole costs of an initial three (3) well drilling program. We estimate that approximately AUD$200,000 (USD$180,600) remains in Terra Nova’s drilling escrow after the drilling of the Wolfman #1 well.

Our Cooper Basin exploration plan includes the acquisition of 3D seismic data on PEL 112 and PEL 444, and the drilling, completion and equipping of six (6) wells shared across both licenses. Current estimates indicate the costs to perform this work could be AUD$37.5 million (USD$33.9 million). Of this amount, approximately AUD$10.9 million (USD$9.8 million) has already been expended. Under the terms of the Terra Nova Farm-In Agreement, we estimate that Terra Nova will bear AUD$19.6 million (USD$17.8 million), we would bear AUD$4.8 million (USD$4.4 million) and our other working interest partners would bear AUD$2.2 million (USD$1.9 million), of planned future exploration costs.

Our operations to date have been financed from contract fees and advances, sales of our securities, loans from unrelated third parties and advances from Holloman Corporation, our current and former officers, directors and their affiliates. We regularly review the market to identify opportunities for capital formation.

In connection with the Terra Nova Farm-In Agreement, Terra Nova paid us cash fees totaling $350,000. We determined that $54,719 of the cash fees paid by Terra Nova were refundable to ACOR and Sakhai under the terms of a cost sharing agreement with them. Of that amount, we have withheld $37,340 as a recovery of exploration costs payable to us by ACOR and Sakhai.

On December 24, 2012 we borrowed $1,000,000 (“Loan”) from LPD Investments Ltd., (“Lender”). The Loan bears interest at 4.5% per annum and provides for a penalty rate of interest of 10% per year on any unpaid principal which is not paid when due. The Loan is payable upon demand of the Lender at any time, and may be prepaid by us without notice or penalty. On August 16, 2013, we voluntarily repaid $60,000 on the Loan, as a result, at December 31, 2013, the principal balance of the Loan was $940,000. The Lender is an unrelated party. Holloman Corporation has guaranteed our obligations under the Loan. Other than this Loan, and the obligations associated with our oil and gas concessions in Australia, we had no material future contractual obligations as of December 31, 2013.

On February 24, 2014, we initiated a non-binding transaction in which we agreed to assign a 1% overriding royalty interest in all production of oil, gas and associated hydrocarbons arising from lands covered by PEL 112 and PEL 444, in exchange for the remaining principal balance of the Loan ($940,000).The completion of this transaction is contingent upon the rejection of first rights of refusal by Terra Nova, ACOR and Sakhai.

On March 1, 2012, we borrowed $100,000 from a consultant who is also a shareholder. This loan was non-interest bearing and payable upon demand. The entire amount of the loan was repaid on March 23, 2012.

During March 2011, we sold 1,400,002 shares of common stock in a private placement of investment units. Proceeds from the private placement totaled $210,000. Of that amount, $180,000 was paid in cash and $30,000 was a conversion of liabilities.

Effective October 1, 2010, we executed an administrative services agreement with Holloman Corporation. Under this agreement, fees of $5,000 per month are payable to Holloman Corporation covering; office and meeting space, supplies, utilities, office equipment, network access and other administrative facilities costs. These fees are payable quarterly in shares of our restricted common stock at the closing price of the stock on the last trading-day of the applicable monthly billing period. This administrative services agreement can be terminated by either party with 30-day notice. During 2013, we recorded $60,000 (2012 – $60,000) of office expense and issued 156,343 (2012– 204,379) shares of our common stock as a result of this agreement.

The oil and gas industry is cyclical in nature and tends to reflect general economic conditions. The US and other world economies are recovering from a recession which continues to inhibit investment liquidity. Though oil prices are trending higher, the pattern of historic price fluctuations has resulted in additional uncertainty in capital markets. Our access to capital, as well as that of our partners and contractors, may be limited due to tightened credit markets. In addition, the results of our operations will be significantly impacted by a variety of trends and factors including; (i) our exploration success and the marketability of future production, if any, (ii) increasing competition from larger companies, (iii) future fluctuations in the prices of oil and gas, and (iv) our ability to maintain or increase oil and gas production through exploration and development activities.

We believe our plan of operations may require up to $10.8 million for exploration costs and administrative expenses over the twelve-month period ending March 31, 2015. We anticipate that our working interest partners will bear up to $8.1 million and that we may bear up to $2.7 million of that amount. We are attempting to raise investment capital to cover our portion of anticipated costs.

If we are unable to raise the financing we need, our business plan may fail and our stockholders could lose their investment. If we are unable to perform in accordance with the work programs required by our licenses, the Australian government could cancel our exploration rights. There can be no assurance that we will be successful in raising the capital we require, or that if capital is offered, it will be subject to terms we consider acceptable. Investors should be aware that even in the event we are able to raise the funds we require, there can be no assurance that we will succeed in our drilling or production plans and we may never be profitable.

As of March 28, 2014 we did not have any off balance sheet arrangements.

As of March 28, 2014 we did not have any proven oil or gas reserves and we did not have any oil and gas revenues.

12

Critical Accounting Policies and Estimates

Measurement Uncertainty

The process of preparing financial statements requires that we make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosure of contingent assets and liabilities at the date of the financial statements, and the reported amounts of revenues and expenses during the reporting period. Such estimates primarily relate to unsettled transactions and events as of the date of the financial statements. Accordingly, actual results may differ from estimated amounts. Our estimates and assumptions are based on current facts, historical experience and various other factors we believe to be reasonable under the circumstances. The most significant estimates with regard to the financial statements included with this report relate to carrying values of oil and gas properties, determination of fair values of stock based transactions, and deferred income tax rates and timing of the reversal of income tax differences.

These estimates and assumptions are reviewed periodically and, as adjustments become necessary, they are reported in earnings in the periods in which they become known.

Petroleum and Natural Gas Properties

We utilize the full cost method to account for our investment in oil and gas properties. Accordingly, all costs associated with acquisition, exploration and development of oil and gas reserves, including such costs as leasehold acquisition costs, interest costs relating to unproved properties, geological expenditures, tangible and intangible development costs, including direct internal costs, are capitalized to the full cost pool. When we commence production from established proven oil and gas reserves, capitalized costs, including estimated future costs to develop the reserves and estimated abandonment costs, net of salvage, will be depleted on the units-of-production method using estimates of proved reserves. Costs of unproved properties are not amortized until the proved reserves associated with the projects can be determined or until impairment occurs. If an assessment of such properties indicates that properties are impaired, the amount of impairment is added to the capitalized cost base to be amortized.

The capitalized costs included in the full cost pool are subject to a "ceiling test", (based on the average of 12 month, first-day-of-the-month pricing), which limits such costs to the aggregate of the (i) estimated present value, using a ten percent discount rate, of the future net revenues from proved reserves, based on current economic and operating conditions, (ii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized, (iii) the cost of properties not being amortized, less (iv) income tax effects related to differences between the book and tax basis of the cost of properties not being amortized and the cost or estimated fair value of unproved properties included in the costs being amortized. At December 31, 2013, all of our oil and gas interests were classified as unproven properties and were not being amortized.

Sales of proved and unproved properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in the statement of operations.

Fair Value Measurements

Our valuation techniques are generally classified into three categories: the market approach; the income approach; and the cost approach. The selection and application of one or more of these techniques requires significant judgment and is primarily dependent upon the characteristics of the asset or liability, the principal (or most advantageous) market in which participants would transact for the asset or liability and the quality and availability of inputs. Inputs to valuation techniques are classified as either observable or unobservable within the following hierarchy:

● Level 1 — quoted prices in active markets for identical assets or liabilities.

● Level 2 — inputs other than quoted prices that are observable for an asset or liability. These include: quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; inputs other than quoted prices that are observable for the asset or liability; and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market-corroborated inputs).  

● Level 3 — unobservable inputs that reflect our own expectations about the assumptions that market participants would use in measuring the fair value of an asset or liability.  

We consider all highly liquid instruments with an original maturity of three months or less at the time of issuance to be cash equivalents. Cash and cash equivalents totaled $23,260 and $1,009,882 at December 31, 2013 and 2012, respectively. We are exposed to a concentration of credit risk with respect to our cash deposits. We place cash deposits with highly rated financial institutions in the United States and Australia. At times, cash balances held in financial institutions may be in excess of insured limits. We believe the financial institutions are financially strong and the risk of loss is minimal. We have not experienced any losses with respect to the related risks and do not believe our exposure to such risks is more than normal.

The estimated fair values for financial instruments are determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. The estimated fair value of cash, other receivables, accounts payable, accrued liabilities and demand notes payable approximates their carrying value due to their short-term nature.

Stock Based Compensation

We record compensation expense for stock based payments using the fair value method. The fair value of stock options granted to directors and employees is determined using the Black-Scholes option valuation model at the time of grant. Fair value for common shares issued for goods or services rendered by non-employees is measured based on the fair value of the goods and services received. Share-based compensation is expensed with a corresponding increase to share capital. Upon the exercise of the stock options, the consideration paid is recorded as an increase in share capital.

13

Foreign Currency Translation

Our functional and reporting currency, and that of our Australian subsidiary, is the United States dollar. The financial statements of our Canadian subsidiary (which is relatively inactive) are translated to United States dollars using period-end rates of exchange for assets and liabilities, and average rates of exchange for the period for revenues and expenses. Translation gains (losses) are recorded in accumulated other comprehensive income as a component of stockholders’ equity. Foreign currency financial statements of our Australian subsidiary use period end rates for monetary assets and liabilities, historical rates for historical cost balances, and average rates for expenses. If material, translation gains and losses are included in the determination of income. Foreign currency transactions are primarily undertaken in Canadian and Australian dollars. As of December 31, 2013, we have not entered into derivative instruments to offset the impact of foreign currency fluctuations.

Other Comprehensive Income (Loss)

We report and display comprehensive loss and its components in our consolidated financial statements. For the years ended December 31, 2013 and 2012, the only components of comprehensive loss were foreign currency translation adjustments.

Income Taxes

We follow the asset and liability method of accounting for future income taxes. Under this method, future income tax assets and liabilities are recorded based on temporary differences between the carrying amount of balance sheet items and their corresponding tax bases. In addition, the future benefits of income tax assets, including unused tax losses, are recognized, subject to a valuation allowance, to the extent that it is more likely than not that such future benefits will ultimately be realized. Future income tax assets and liabilities are measured using enacted tax rates and laws expected to apply when the tax liabilities or assets are to be either settled or realized.

Earnings per share

We present both basic and diluted earnings (loss) per share (EPS) on the face of the consolidated statements of operations. Basic EPS is computed by dividing net earnings (loss) available to common shareholders by the weighted average number of shares outstanding during the period. Diluted EPS gives effect to all potential dilutive common shares outstanding during the period including convertible debt, stock options, and warrants, using the treasury stock method. Diluted EPS excludes all potential dilutive shares if their effect is anti-dilutive. Diluted EPS figures are equal to those of basic EPS for each period since we had no securities outstanding during periods in which we generated net income that were potentially dilutive.

See Note 2 to our consolidated financial statements for a discussion of recent accounting pronouncements.

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.

Attached.

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURES.

None.

ITEM 9A. CONTROLS AND PROCEDURES.

An evaluation was carried out under the supervision and with the participation of our management, including our Principal Financial Officer and Principal Executive Officer, of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this report on Form 10-K. Disclosure controls and procedures are procedures designed with the objective of ensuring that information required to be disclosed in our reports filed under the Securities Exchange Act of 1934, such as this Form 10-K, is recorded, processed, summarized and reported, within the time period specified in the Securities and Exchange Commission’s rules and forms, and that such information is accumulated and is communicated to our management, including our Principal Executive Officer and Principal Financial Officer, or persons performing similar functions, as appropriate, to allow timely decisions regarding required disclosure. Based on our evaluation, management concluded that, as of December 31, 2013, our disclosure controls and procedures were effective.

14

Management’s Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting as required by Sarbanes-Oxley (SOX) Section 404.A. Our internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with generally accepted accounting principles in the United States and includes those policies and procedures that:

(1) Pertain to the maintenance of records that in reasonable detail accurately and fairly reflect the transactions and dispositions of the assets;

(2) Provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and our receipts and expenditures are being made only in accordance with authorizations of management and directors; and

(3) Provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on our financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Therefore, even those systems determined to be effective can provide only reasonable assurance of achieving their control objectives. In evaluating the effectiveness of our internal control over financial reporting, our management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control - Integrated Framework. Based on that evaluation, management concluded that during the period covered by this report our internal control over financial reporting was effective as of December 31, 2013.

ITEM 9B. OTHER INFORMATION

None

15

PART III

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE.

Name	Age	Position
Mark Stevenson	59	Chairman of the Board of Directors, President, Chief Executive Officer, and Secretary
Eric Prim	55	Chief Operating Officer, and Director
Robert Wesolek	57	Chief Financial Officer, Chief Accounting Officer and Treasurer
J. Douglas Brown	61	Director
Keith Macdonald	57	Director

Our Directors are elected for a one-year term and hold office until the next annual meeting of our shareholders or until their resignation or removal by a vote of our shareholders. Officers are appointed by the Board of Directors and serve at the discretion of the Board. There is no family relationship between or among any of our Directors or Officers.

Mark Stevenson, Chairman of the Board of Directors, President, Chief Executive Officer, and Secretary

Mark Stevenson was appointed as our President and Chief Executive Officer on July 1, 2009. Mr. Stevenson became a member of our Board of Directors on September 20, 2007 and was elected Chairman of that Board on January 4, 2008. Mr. Stevenson has been the President and Chief Executive Officer of Holloman Corporation (Houston, TX) since July 1998. Holloman Corporation is one of the largest employee owned engineering and construction companies in the United States. Prior to his appointment as President, Mr. Stevenson was employed by Holloman Corporation as Executive Vice President (1997-1998), Vice President - Pipeline Division (1979-1997) chief estimator (1977-1979) and field construction engineer (1976-1977). He joined Holloman Corporation in 1976, after receiving his B.S. in Construction Engineering from Texas Tech University in Lubbock. Mr. Stevenson has also served as a director of Terra Nova Energy Ltd., (TSVX) during the period from August 2012 to September 2013.

Eric Prim, Chief Operating Officer, and Director

Eric Prim joined our Board of Directors on September 20, 2007. On July 22, 2009, Mr. Prim was also appointed as our Chief Operating Officer. Mr. Prim is the President of Pilot Energy Solutions, and has been the Senior Vice President of Holloman Corporation since 1997. He has served as a director of EFLO Energy, Inc. (OTCQB) since March 2011. Prior to his association with Holloman, Mr. Prim held senior technical management positions with Hunt Energy (1982-1987) and Rexene Corporation (1987-1997). Mr. Prim holds a B.S. in Chemical Engineering from The University of Texas (1982) and an M.B.A. from Amber University (1987). Mr. Prim is a registered Professional Engineer in Texas and holds thirteen (13) issued or pending U.S. Patents, all pertaining to energy technology.

Robert Wesolek CPA, Chief Financial Officer, Chief Accounting Officer and Treasurer

Robert Wesolek has been the Chief Financial Officer of Holloman Energy Corporation since August 4, 2009, and has served as a director of EFLO Energy, Inc (OTCQB) since June 2011. Wesolek has acted as an executive consultant providing financial, regulatory and system design services to emerging corporations since 2006. In July, 2013, Mr. Wesolek also joined Pacific Hunt Energy Corp. as a director and its Chief Financial Officer. Prior to 2006, Mr. Wesolek served as Chief Financial Officer and director of Brussels Chocolates Inc. (2004-2006), President and Chief Executive Officer of The Navigates Corporation (1998-2004), Chief Financial Officer of Sharp Technology Inc. (1998-2001), President of the Desktop Software Division of Citadel Security Software (1996-1998), and Chief Operating Officer of Kent Marsh Ltd., Inc. (1988-1996). During the period from 1980 to 1988, Mr. Wesolek was a Senior Practice Manager in the Audit Division of Arthur Andersen LLP.

J. Douglas Brown, Director

J. Douglas Brown joined our Board of Directors on March 19, 2007 and is Chairman of our Audit Committee. Mr. Brown graduated with a law degree (LLB), from Edinburgh University in 1973. He began his banking career as a financial analyst with J P Morgan in London and New York and worked as an investment banker from 1982 to 1987 with Banque Indosuez. From 1988 through 1997, Mr. Brown was a Vice President with Citigroup’s London and Geneva offices providing investment banking services to the Middle East. Since 1997, Mr. Brown has been active in the hedge fund business. He is on the board of two funds, LIM Multi Strategy Fund and Eastern Capital Fund and jointly manages a privately-owned hedge fund distribution business. He is also involved with corporate finance transactions both as an investor and adviser.

Keith MacDonald, Director

Keith Macdonald, CA joined our Board on August 4, 2009. Keith Macdonald has been President of Bamako Investment Management Ltd., a private holding and financial advisory company since 1994. Mr. Macdonald currently serves on the board of Bellatrix Exploration Ltd. (TSX), Madalena Ventures Inc. (TSXV), Surge Energy Inc. (TSX), and Mountainview Energy Ltd. (TSXV). Most recently, he was a director of Rocky Mountain Dealership Inc. (TSX), WCSB Oil & Gas Royalty Income Funds, Profound Energy Inc. (TSX), Cordy Oilfield Services Inc.(TSXV), Stratabound Minerals Inc.(TSXV) and Breaker Energy Ltd (TSX) , and prior thereto a director of several public and private oil and gas companies. Mr. Macdonald was founder, President and Director of New Cache Petroleums from 1987 until its amalgamation in 1994 and thereafter Chief Financial Officer and Director until its sale in 1999. He is a past Chairman and director of the Small Explorers and Producers of Canada.

16

We believe our directors benefit us as a result of their expertise in the following areas:

Name	Area of Expertise
Mark Stevenson	Oil and gas
Eric Prim	Oil and gas
J. Douglas Brown	Oil and gas, and corporate finance
Keith MacDonald	Oil and gas

On November 21, 2007, we acquired Holloman Petroleum Pty. Ltd. for 18,600,000 shares of our common stock. As a condition of this acquisition, Mark Stevenson, President and CEO of Holloman Corporation, and Eric Prim, Vice President of Holloman Corporation, were appointed to our Board of Directors.

J. Douglas Brown and Keith Macdonald are independent directors, as that term is defined in Section 803 of the listing standards of the NYSE MKT. Mr. Brown and Mr. Macdonald comprise our Audit Committee. Mr. Macdonald is our Audit Committee financial expert as that term is defined in Item 407 of Regulation S-K of the Securities and Exchange Commission. Mr. Macdonald is qualified to act in that capacity by virtue of his extensive experience as a Chartered Accountant and senior financial officer in enterprises similar, or more mature than ours. In those capacities, both Mr. Macdonald has been responsible for the review and analysis of financial statements including the application and assessment of accounting principles, and the implementation and assessment of internal controls.

We do not have a separate nominating committee. Our entire Board of Directors act as our nominating committee.

On March 26, 2007, our Board of Directors adopted a code of ethics that applies to our principal executive and financial officers. A copy of our Code of Ethics was included as Exhibit 14.1 to our Form 10-KSB for our year ended December 31, 2006 and is also available in the “Investors” section of our website at www.hollomanenergy.com.

Compensation Committee Interlocks and Insider Participation

We do not have a separate compensation committee. Our Board of Directors acts as our compensation committee. During the year ended December 31, 2013, all of our directors participated in deliberations concerning executive officer compensation.

During the year ended December 31, 2013, our Chief Operating Officer, Eric Prim, Chief Financial Officer, Robert Wesolek, and Director, Keith Macdonald were directors with the authority to approve compensation decisions for  EFLO Energy, Inc., an OTCQB natural resources exploration company. Mr. Macdonald and Mr. Wesolek are executive officers of that company.

Except for the foregoing, during the year ended December 31, 2013 none of our officers served as a compensation committee member or director of another entity whose officer(s) also served as one of our directors.

Compliance with Section 16A of the Exchange Act

Section 16(a) of the Securities Exchange Act of 1934, as amended, requires that our directors and executive officers and persons who beneficially own more than 10% of our common stock (referred to herein as the “reporting persons”) file with the Securities and Exchange Commission various reports as to their ownership of and activities relating to our common stock. Such reporting persons are required by the SEC regulations to furnish us with copies of all Section 16(a) reports they file. Based solely upon a review of copies of Section 16(a) reports and representations received by us from reporting persons, and without conducting any independent investigation of our own, we believe all Forms 3, 4 and 5 were timely filed with the Securities and Exchange Commission by such reporting persons, with the exception of Holloman Value Holdings LLC (our controlling shareholder) which filed one Form 4 covering four transactions after their due dates. These transactions related entirely to the conversion of administrative service fees to shares of our common stock.

17

ITEM 11. EXECUTIVE COMPENSATION.

The following table shows the compensation accrued or paid to our Chief Executive Officer, Chief Financial Officer, and those executive officers that earned more than $100,000 in 2013 and 2012:

Summary Compensation Table

Name and Principal		Salary		Bonus		Stock Awards		Option Awards		All Other Compensation		Total
Position	Year	($)		($)		($)		($)		($) (3)		($)
Mark Stevenson (1)	2013		––		––		––		––		––		––
Chief Executive Officer	2012		––		––		21,750		104,874		27,619		154,243
Robert Wesolek (2)	2013		118,028		––		––		––		––		118,028
Chief Financial and Accounting Officer	2012		111,525		––		––		––		27,619		139,144

(1)	During the year ended December 31, 2012, Mr. Stevenson was granted 75,000 shares of stock (fair value $21,750) and stock options providing for the purchase of 1,800,000 shares of stock (fair value $104,874) under our 2009 Stock Bonus and Options Plans (see details below) as compensation for his services as an officer and director.
(2)	Mr. Wesolek is compensated in the form of fees for services rendered in the normal course of operations. The amount of the fees was established and approved by our Board of Directors. As of December 31, 2013, $42,475 in fees payable to Mr. Wesolek remained unpaid.
(3)	On April 2, 2012, our Board of Directors consented to the distribution of 666,670 shares of the common stock of Terra Nova to our directors, officers and principal advisors. We received the Terra Nova shares in connection with the Agreement with Terra Nova, and they were distributed as compensation for efforts put forth in securing that opportunity. The fair market value of the Terra Nova shares was the market price of the shares at the date they were earned by us. Mr. Stevenson and Mr. Wesolek each received 95,239 shares of Terra Nova stock with a value of $27,619, or $0.29 per share.

In August 15, 2009, we issued our officers and directors fractional participation in a 2% net revenue interest in wells drilled by us on lands in the Cooper Basin. Additional participation was granted to one officer during April, 2012. These participation units represent a 0.62% interest in our Cooper Basin revenues, after all royalties, exploration expenses, operating costs and capital investments associated with the Cooper Basin have been recovered. In our opinion no value can be assigned to these revenue interests, as any valuation cannot be estimated.

We do not have employment agreements with our officers.

We do not have any annuity, pension or retirement plans.

Stock-Based Compensation

On August 15, 2009, we established a Non-Qualified Stock Option Plan and a Stock Bonus Plan. The Non-Qualified Stock Option Plan (the “Option Plan”) authorizes the issuance of up to 7,200,000 shares of our common stock. Under the Stock Bonus Plan up to 300,000 shares (“Bonus Shares”) of our common stock may be issued to employees, directors, officers, consultants and advisors, provided qualifying services are rendered.

At the discretion of our Board of Directors, any option may include installment exercise terms such that the option becomes fully exercisable in a series of cumulating portions. Any options granted or shares issued pursuant to the Plans will be forfeited if the "vesting" schedule established at the time of the grant is not met. We may at any time, and from time to time, amend, terminate, or suspend one or more of the Plans in any manner we deem appropriate, provided that any amendment, termination or suspension may not adversely affect rights or obligations with respect to options or shares previously granted.

During the fiscal year ended December 31, 2013, no options were granted, exercised or forfeited by our officers or directors pursuant to our Non-Qualified Stock Option Plan.

The following table shows the options held by our officers and directors as of December 31, 2013. The options in the table were all granted pursuant to our Non-Qualified Stock Option Plan.

18

Outstanding Equity Awards at December 31, 2013

	Number of securities underlying unexercised options
		(#)		(#)	Option Exercise		Option Expiration
Name	Exercisable		Unexercisable		Price		Date
Eric Prim
Stock Option C		300,000		––	$	1.00	August 15, 2014
Stock Option D		300,000		––	$	1.20	August 15, 2014
Robert Wesolek
Stock Option C		150,000		––	$	1.00	August 15, 2014
Stock Option D		150,000		––	$	1.20	August 15, 2014
J.Douglas Brown
Stock Option C		300,000		––	$	1.00	August 15, 2014
Stock Option D		300,000		––	$	1.20	August 15, 2014
Keith Macdonald
Stock Option C		300,000		––	$	1.00	August 15, 2014
Stock Option D		300,000		––	$	1.20	August 15, 2014
Mark Stevenson
Stock Option C		450,000		––	$	1.00	August 15, 2014
Stock Option D		450,000		––	$	1.20	August 15, 2014

_________________

The following table shows the weighted average exercise price of the outstanding options granted pursuant to our Non-Qualified Stock Option Plan as of December 31, 2013. Our Non-Qualified Stock Option Plan has not been approved by our shareholders.

Plan category	Number of securities to be issued upon exercise of outstanding options,  warrants and rights		Weighted-average exercise price of outstanding options, warrants and rights		Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a))
	(a)		(b)		(c)(1)
Non-Qualified Stock Option Plan		3,300,000	$	1.10		3,925,000
Total		3,300,000	$	1.10		3,925,000

——————— 

(1) The number of securities remaining available for future issuance includes 25,000 shares of our common stock available for issuance under the terms of the Stock Bonus plan.

On April 3, 2012 we issued 75,000 shares of our common stock to Mark Stevenson, our Chief Executive Officer, pursuant to our Stock Bonus Plan.

At December 31, 2012, 3,900,000 options and 25,000 shares of our common stock, respectively, remain available for distribution under our Option Plan and Stock Bonus Plan.

We have never offered any annuity, pension or retirement benefits for our officers, directors or employees.

19

Director’s Compensation

Our directors are reimbursed for reasonable out-of-pocket expenses in connection with attendance at Board of Director and committee meetings. During the year ended December 31, 2013, no compensation was paid to any of our directors.

ITEM 12.  SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS.

The following table shows as of March 28, 2014, the beneficial ownership of shares of common stock by (i) each person known to us who owns beneficially more than 5% of the outstanding shares of common stock, (ii) each of our Officers and Directors and (iv) all of our Executive Officers and Directors as a group. Unless otherwise indicated, each stockholder has, or shares, voting and investment power with respect to the shares shown.

Name and address of beneficial owner	Number of Shares (1)			Percentage of Common Stock
Mark Stevenson	49,901,156		(2&3)		44.82	%
Chairman of the Board, Chief Executive Officer,
President and Secretary
333 North Sam Houston Parkway East
Suite 600
Houston, TX 77060
Eric Prim		49,636,416	(4)		44.70	%
Chief Operating Officer and Director
4514 Siandra Creek Court
Houston, Texas 77386
Robert Wesolek		3,212,500			2.90	%
Chief Financial Officer, Chief Accounting Officer and Treasurer
3 Farther Point
Houston, TX 77024
J. Douglas Brown		4,365,098			3.93	%
Director
16E Les Roseyres, Gron1882
Vaud, Switzerland
Keith Macdonald		1,104,167	(5)		0.99	%
Director
203 Heritage Place
Calgary, AB, Canada T3Z 3P3
Holloman Value Holdings, LLC		48,169,590			43.62	%
333 North Sam Houston Parkway East
Suite 600
Houston, Texas 77060
All Officers and Directors as a group (five persons)		60,049,747			52.94	%

——————

(1) Includes shares which may be acquired on the exercise of options or warrants listed below, all of which were exercisable as of March 30, 2013.

20

	Shares Issuable Upon
Name	Exercise of Warrants		Exercise Price		Expiration Date
Mark Stevenson		450,000	$	1.00	08/15/2014
Mark Stevenson		450,000	$	1.20	08/15/2014
Eric Prim		300,000	$	1.00	08/15/2014
Eric Prim		300,000	$	1.20	08/15/2014
Robert Wesolek		150,000	$	1.00	08/15/2014
Robert Wesolek		150,000	$	1.20	08/15/2014
J. Douglas Brown		300,000	$	1.00	08/15/2014
J. Douglas Brown		300,000	$	1.20	08/15/2014
Keith Macdonald		300,000	$	1.00	08/15/2014
Keith Macdonald		300,000	$	1.20	08/15/2014

———————

(2) Includes 429,745 shares held directly and 401,821 shares held indirectly by entities (excluding Holloman Value Holdings, LLC – Note 3) controlled by Mr. Stevenson, and shares issuable upon the exercise of warrants (Note 1).

(3) Mark Stevenson is the President of Holloman Corporation. Holloman Corporation controls Holloman Value Holdings, LLC. Accordingly, Mr. Stevenson’s holdings include 48,169,590 shares owned of record by Holloman Value holdings, LLC.

(4)	Eric Prim is a Director of Holloman Value Holdings. Accordingly, Mr. Prim’s holdings include 48,169,590 shares owned of record by Holloman Value Holdings, LLC.
(5)	All shares are held indirectly by an entity controlled by Mr. Macdonald, and shares issuable upon the exercise of warrants

Securities authorized for issuance under equity compensation plans are detailed in Item 11 of this report.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE.

In November 2007 we acquired Holloman Petroleum for 18,600,000 shares of our common stock. Prior to the acquisition, Holloman Petroleum was a majority owned subsidiary of Holloman Oil & Gas Pty Ltd., which is a wholly-owned subsidiary of Holloman Corporation (see Item 1).

As detailed in our financial statements and Items 1 and 7 of this report, from time to time, we have non-interest bearing notes and advances from certain of our Directors, shareholders and affiliates; and a series of transactions with Holloman Corporation, Holloman Value Holdings, LLC, and Holloman Oil & Gas Pty Ltd. Holloman Corporation, controls Holloman Value Holdings, LLC and Holloman Oil & Gas Pty Ltd.

Holloman Corporation, through its wholly-owned subsidiary Holloman Value Holdings, LLC is our parent corporation. As of March 28, 2014 Holloman Value Holdings, LLC owned 48,169,590 shares (44%) of our outstanding common stock. Mark Stevenson, our Chairman and Chief Executive Officer, and Eric Prim, our Director and Chief Operating Officer, are both senior executives with Holloman Corporation.

ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES.

The following table sets forth the aggregate fees paid or accrued for professional services rendered by Weaver and Tidwell, L.L.P. (“Weaver”) for the audit of our annual financial statements for 2013 and 2012, and the aggregate fees paid or accrued for audit-related services and all other services rendered by Weaver for those years.

	2013		2012
Audit-related fees		65,500		67,500
Tax fees		6,550		––
Total	$	72,050	$	67,500

The category of “Audit-related fees” includes fees for our annual audit, quarterly reviews and services rendered in connection with regulatory filings with the SEC. “Tax fees” include fees incurred in the review and preparation of our annual income tax filings.

The Audit Committee of our Board of Directors pre-approves the scope and estimated costs of all services rendered by our Principal Accountants. We concluded that the services provided by Weaver were compatible with the maintenance of each firms’ independence in the conduct of its auditing functions.

21

PART IV

ITEM 15.  EXHIBITS, FINANCIAL STATEMENT SCHEDULES.

FINANCIAL STATEMENTS

Consolidated Balance Sheets

Consolidated Statements of Operations

Consolidated Statements of Cash Flows

Consolidated Statements of Stockholders Equity (Deficit)

Notes to Consolidated Financial Statements

EXHIBITS

Exhibit Number	Description of Exhibit
3.1	Articles of Incorporation(1)
3.2	Corporate Bylaws(1)
10.1	Share Exchange Agreement between Endeavor Energy Corporation, First Endeavor Holdings Inc. and Endeavor Canada Corporation(2)
10.2	Agreement between Endeavor Energy Corporation and Holloman Petroleum Pty. Ltd. for the  purchase of assets and exchange of shares(3)
10.3	Option Agreement between Holloman Energy Corporation and Cameron King for an exchange of shares of Endeavor Canada Corporation(4)
10.4	Notice of Option Exercise relating to the Option Agreement between Holloman Energy Corporation and Cameron King for an exchange of shares of Endeavor Canada Corporation(4)
10.5	Farm Out Commitment Agreement between Holloman Energy Corporation and Holloman Oil &   Gas, Ltd.(4)
10.6	Brandenburg  Oil & Gas Farm-In Agreement, Petroleum Exploration Licenses 112 and 444 dated July 29, 2011(6)
10.7	Terra Nova Oil & Gas Farm-In Agreement, PELs 112 and 444, and Letter Agreement – Transaction Cost Sharing (7)
14.1	Code of Ethics for Principal Executive and Senior Financial Officers(5)
21.1	As of December 31, 2013 our subsidiaries were:
	First Endeavor Holdings Inc. (100% Owned) Alberta corporation
	Holloman Petroleum Pty. Ltd. (100% Owned) Australian corporation
	Endeavor Exploration Pty. Ltd. (100% Owned) Australian corporation
	All subsidiaries conduct business under their own names
31.1	Rule 13a-14(a) Certifications
31.2	Rule 13a-14(a) Certifications
32	Section 1350 Certifications
101. INS	XBRL Instance Document
101. SCH	XBRL Schema Document
101. CAL	XBRL Calculation Linkbase Document
101. DEF	XBRL Taxonomy Extension Definition Linkbase Document
101. LAB	XBRL Label Linkbase Document
101. PRE	XBRL Presentation Linkbase Document

———————

(1) Previously filed with our Form SB-2 on January 23, 2006 and incorporated by reference.

(2) Previously filed with our Form 8-K on August 9, 2007 and incorporated by reference.

(3) Previously filed with our Form 8-K on November 29, 2007 and incorporated by reference.

(4) Previously filed with our Form 10-KSB on April 15, 2008 and incorporated by reference.

(5)	Previously filed with our Form 10-KSB/A on April 26, 2007 and incorporated by reference.
(6)	Previously filed with our Form 8-K on August 4, 2011 and incorporated by reference.

22

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders

of Holloman Energy Corporation

(An Exploration Stage Company)

We have audited the accompanying consolidated balance sheets of Holloman Energy Corporation and Subsidiaries (an Exploration Stage Company) (the Company) as of December 31, 2013 and 2012, and the related consolidated statements of operations, stockholders’ equity, and cash flows for each of the years in the two-year period ended December 31, 2013, and for the period from inception (May 5, 2006) to December 31, 2013. The Company’s management is responsible for these consolidated financial statements. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

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

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Holloman Energy Corporation and Subsidiaries (an Exploration Stage Company) as of December 31, 2013 and 2012, and the consolidated results of its operations and its cash flows for each of the years in the two-year period ended December 31, 2013 and for the period from inception (May 5, 2006) to December 31, 2013 in conformity with accounting principles generally accepted in the United States of America.

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 1 to the consolidated financial statements, the Company has not generated operating revenues, incurred losses since inception, has not attained profitable operations and is dependent upon obtaining adequate financing to fulfill its exploration activities. The Company requires additional funds to meet its obligations and the costs of its operations. These factors raise substantial doubt about the Company’s ability to continue as a going concern. Management’s plans in this regard are described in Note 1 to the consolidated financial statements. The consolidated financial statements do not include any adjustments that might result from the outcome of this uncertainty.

/s/ Weaver and Tidwell, L.L.P._____

WEAVER AND TIDWELL, L.L.P.

Houston, Texas

March 28, 2014

AN INDEPENDENT	WEAVER AND TIDWELL LLP
MEMBER OF BAKER TILLY	CERTIFIED PUBLIC ACCOUNTANTS AND CONSULTANTS	24 GREENWAY PLAZA, SUITE 1800,
		HOUSTON, TX 77046
INTERNATIONAL	WWW.WEAVERLLP.COM	P: (713) 850 8787     F: (713) 850 1673

23

HOLLOMAN ENERGY CORPORATION

(An Exploration Stage Company)

CONSOLIDATED BALANCE SHEETS

	December 31, 2013			December 31, 2012
ASSETS
ASSETS
Cash	$	23,260		$	1,009,882
Other receivable		1,256			1,468
Prepaid expenses		8,447			6,657
Current Assets		32,963			1,018,007
Oil and gas properties, full cost method, unproven		17,185,618			16,629,162
Total Assets	$	17,218,581		$	17,647,169
LIABILITIES AND STOCKHOLDERS' EQUITY
LIABILITIES
Accounts payable and accrued liabilities	$	237,133		$	212,769
Note payable		940,000			1,000,000
Current Liabilities		1,177,133			1,212,769
Deferred tax liability		4,992,436			4,909,617
Total Liabilities		6,169,569			6,122,386
STOCKHOLDERS' EQUITY
Authorized:
10,000,000 preferred shares, par value $0.001 per share
150,000,000 common shares, par value $0.001 per share
Issued and outstanding :
110,433,321 common shares (110,276,978 at December 31, 2012)		110,433			110,277
Additional paid in capital		25,888,388			25,828,544
Accumulated other comprehensive loss		(2,401	)		(8,898	)
Deficit accumulated during the exploration stage		(14,947,408	)		(14,405,140	)
Total Stockholders' Equity		11,049,012			11,524,783
Total Liabilities and Stockholders' Equity	$	17,218,581		$	17,647,169

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

24

HOLLOMAN ENERGY CORPORATION

(An Exploration Stage Company)

CONSOLIDATED STATEMENTS OF OPERATIONS

	Cumulative results from
	May 5, 2006 (Inception)			Years Ended December 31,
	to December 31, 2013			2013			2012
CONTINUING OPERATIONS
Expenses
Consulting	$	1,678,147		$	61,318		$	405,216
Foreign exchange (gain) loss		255,707			(746,669	)		98,491
Gain on settlement of debt		(40,026	)		-			-
Management and director's fees		1,471,898			118,028			271,393
Stock-based compensation expense		2,511,212			-			104,874
Office, travel and general		946,551			122,002			115,068
Professional fees		873,633			114,364			100,964
Salaries, wages, and benefits		86,666			-			-
Bad debt expense		3,395			-			3,395
Total Expenses		(7,787,183	)		330,957			(1,099,401	)
Other income and expense
Oil and gas property impairment		(7,396,207	)		-			-
Deferred income tax recovery		2,244,107			-			-
Interest expense		(44,650	)		(44,650	)		-
Other Income		535,869			-			495,775
Income (Loss) from Continuing Operations		(12,448,064	)		286,307			(603,626	)
DISCONTINUED OPERATIONS
Loss from discontinued operations		(2,454,637	)		-			-
Gain on disposal of Endeavor		783,868			-			-
Loss from Discontinued Operations		(1,670,769	)		-			-
INCOME (LOSS) BEFORE TAXES		(14,118,833	)		286,307			(603,626	)
Provision for income tax		(828,575	)		(828,575	)		-
NET LOSS	$	(14,947,408	)	$	(542,268	)	$	(603,626	)
Foreign currency translation		(2,401	)		6,497			3,445
COMPREHENSIVE LOSS	$	(14,949,809	)	$	(535,771	)	$	(600,181	)
BASIC AND DILUTED NET LOSS FROM CONTINUING OPERATIONS PER COMMON SHARE				$	(0.00	)	$	(0.01	)
BASIC AND DILUTED NET LOSS FROM DISCONTINUED OPERATIONS PER COMMON SHARE				$	(0.00	)	$	(0.00	)
BASIC AND DILUTED NET LOSS PER COMMON SHARE				$	(0.00	)	$	(0.01	)
WEIGHTED AVERAGE NUMBER OF BASIC AND DILUTED COMMON SHARES OUTSTANDING					110,330,146			109,784,955

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

25

HOLLOMAN ENERGY CORPORATION

(An Exploration Stage Company)

CONSOLIDATED STATEMENTS OF CASH FLOWS

				Years Ended December 31,
	Cumulative results from May 5, 2006 (Inception) to December 31, 2013			2013			2012
OPERATING ACTIVITIES
Net loss	$	(14,947,408	)	$	(542,268	)	$	(603,626	)
Adjustments to reconcile net loss to net cash
used in operating activities:
Cash used by discontinued operations		1,729,701			-			-
Gain on disposal of Endeavor		(783,868	)		-			-
Gain from settlement of indebtedness		(65,026	)		-			-
Stock-based compensation and fee payments		3,339,212			-			416,624
Unrealized foreign exchange (gain) loss		213,759			(739,259	)		101,666
Impairment of oil and gas properties (net of tax recovery)		5,152,100			-			-
Deferred income tax provision		828,575			828,575			-
Changes in working capital items
Other receivable		(1,256	)		212			2,418
Prepaid expenses		(8,447	)		(1,790	)		(1,918	)
Accounts payable and accrued liabilities		542,843			31,508			84,467
Contract advances		131,190			-			(7,160	)
Cash used in operating activities		(3,868,625	)		(423,022	)		(7,529	)
INVESTING ACTIVITIES
Investing activities from discontinued operations		(1,447,739	)		-			-
Oil and gas expenditures		(1,910,585	)		(503,600	)		(31,567	)
Oil and gas expenditures recovered from partners		37,340			-			37,340
Cash acquired on acquisition		12,696			-			-
Deposit on acquisition		(639,487	)		-			-
Cash provided by (used in) investing activities		(3,947,775	)		(503,600	)		5,773
FINANCING ACTIVITIES
Financing activities from discontinued operations		2,000,261			-			-
Common stock issued for cash		3,505,001			-			-
Loans payable		1,050,567			-			1,000,000
Loan Repayments		(60,000	)		(60,000	)		-
Related party repayments		(100,000	)		-			(100,000	)
Proceeds from related parties		1,443,831			-			100,000
Cash provided by (used in) financing activities		7,839,660			(60,000	)		1,000,000
CHANGE IN CASH		23,260			(986,622	)		998,245
CASH, BEGINNING		-			1,009,882			11,637
CASH, ENDING	$	23,260		$	23,260		$	1,009,882
SUPPLEMENTAL DISCLOSURE:
Cash paid for interest	$	56,063		$	44,965		$	1,190
NON-CASH INVESTING ACTIVITIES:
Accrued capital expenditures in oil and gas properties	$	52,857		$	52,857		$	-
NON-CASH FINANCING ACTIVITIES:
Shares issued for management fees	$	231,750		$	-		$	21,750
Shares issued for services	$	485,000		$	60,000		$	350,000
Shares issued on conversion of liabilities	$	2,661,879		$	-		$	-
Shares issued for property acquired	$	15,903,000		$	-		$	-

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

26

HOLLOMAN ENERGY CORPORATION

(An Exploration Stage Company)

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (DEFICIT)

From May 5, 2006 (Inception) to December 31, 2013

																			Deficit
																Accumulated			Accumulated
	Common Shares						Preferred Shares						Additional			Other			During			Total
	Number						Number						Paid In			Comprehensive			Exploration			Stockholders'
	of Shares			Amount			of Shares			Amount			Capital			Income/(Loss)			Stage			Equity
Issuance of common shares to
to founder, May 2006		100		$	1			-		$	-		$	-		$	-		$	-		$	1
Comprehensive income (loss)
Net loss for the 8 months
ended December 31, 2006		-			-			-			-			-			-			(1,462,407	)		(1,462,407	)
Foreign currency translation		-			-			-			-			-			13,987			-			13,987
Total Comprehensive loss																							(1,448,420	)
Balance, December 31, 2006		100			1			-			-			-			13,987			(1,462,407	)		(1,448,419	)
Issued by the Company on acquisition of
ECC in August 2007		-			-			9,000			9			-			-			-			9
Issued by FEH on acquisition of  ECC
in August, 2007		-			-			9,000,000			9,000			(9,000	)		-			-			-
Adjustment to give effect to acquisition of
ECC in August, 2007		61,466,203			61,466			-			-			329,766			-			-			391,232
Shares of ECC acquired by legal parent		(100	)		(1	)		-			-			-			-			-			(1	)
Issued at $1.50 per share in August 2007
on conversion of ECC debentures		1,093,155			1,093			-			-			1,638,640			-			-			1,639,733
Issued for cash at $1.00 per share		60,000			60			-			-			59,940			-			-			60,000
Issued for property at $0.86 per share		18,600,000			18,600			-			-			15,884,400			-			-			15,903,000
Comprehensive loss
Net loss		-			-			-			-			-			-			(1,507,745	)		(1,507,745	)
Foreign currency translation		-			-			-			-			-			(44,857	)		-			(44,857	)
Total Comprehensive loss																							(1,552,602	)
Balance, December 31, 2007		81,219,358		$	81,219			9,009,000		$	9,009		$	17,903,746		$	(30,870	)	$	(2,970,152	)	$	14,992,952
Write Off Accumulated Comprehensive
Income from ECC operations to
Extraordinary Gain		-			-			-			-			-			31,265			(70	)		31,195
Preferred shares cancelled by the
Company on divestiture of ECC
February 2008		-			-			(6,500	)		(6	)		-			-			-			(6	)
Prefrerred shares cancelled by FEH
on divestiture of ECC February 2008		-			-			(6,500,000	)		(6,500	)		-			-			-			(6,500	)
Conversion of preferred shares to
common stock		2,502,500			2,503			(2,502,500	)		(2,503	)		-			-			-			-
Investment Units issued for cash at $0.30
per unit		2,766,668			2,767			-			-			744,233			-			-			747,000
Investment Units issued for cash at $0.255
per unit		6,664,706			6,664			-			-			1,618,335			-			-			1,624,999
Management fees converted to
common stock		2,005,833			2,006			-			-			197,987			-			-			199,993
Comprehensive income
Net income		-			-			-			-			-			-			808,322			808,322
Foreign currency translation		-			-			-			-			-			1,219			-			1,219
Total Comprehensive income																							809,541
Balance, December 31, 2008		95,159,065			95,159			-			-			20,464,301			1,614			(2,161,900	)		18,399,174
Conversion of indebtedness to
commmon stock		9,385,935			9,386			-			-			929,207			-			-			938,593
Issued for services		700,000			700			-			-			315,550			-			-			316,250
Investment units issued for cash at $0.48
per unit		1,860,416			1,860			-			-			891,140			-			-			893,000
Conversion of indebtedness to investment
units		132,404			133			-			-			63,421			-			-			63,554
Stock-based compensation granted		-			-			-			-			1,143,379			-			-			1,143,379
Comprehensive loss
Net loss		-			-			-			-			-			-			(8,650,016	)		(8,650,016	)
Foreign currency translation		-			-			-			-			-			(4,540	)		-			(4,540	)
Total Comprehensive loss																							(8,654,556	)
Balance, December 31, 2009		107,237,820			107,238			-			-			23,806,998			(2,926	)		(10,811,916	)		13,099,394
Issued for services		69,445			69			-			-			14,931			-			-			15,000
Stock-based compensation granted		-			-			-			-			1,066,126			-			-			1,066,126
Comprehensive loss
Net loss		-			-			-			-			-			-			(2,466,997	)		(2,466,997	)
Foreign currency translation		-			-			-			-			-			(5,733	)		-			(5,733	)
Total Comprehensive loss																							(2,472,730	)
Balance, December 31, 2010		107,307,265			107,307			-			-			24,888,055			(8,659	)		(13,278,913	)		11,707,790
Investment units issued for cash at $0.15
per unit		1,200,001			1,200			-			-			178,800			-			-			180,000
Investment units issued for services		133,334			134			-			-			19,866			-			-			20,000
Conversion of indebtness to investment
units		66,667			67			-			-			9,933			-			-			10,000
Issued for services		290,332			290			-			-			59,710			-			-			60,000
Stock-based compensation granted		-			-			-			-			196,835			-			-			196,835
Comprehensive loss
Net loss		-			-			-			-			-			-			(522,601	)		(522,601	)
Foreign currency translation		-			-			-			-			-			(3,684	)		-			(3,684	)
Total Comprehensive loss																							(526,285	)
Balance, December 31, 2011		108,997,599			108,998			-			-			25,353,199			(12,343	)		(13,801,514	)		11,648,340
Stock-based compensation granted		75,000			75			-			-			126,549			-			-			126,624
Issued for services		1,204,379			1,204			-			-			348,796			-			-			350,000
Comprehensive loss
Net loss		-			-			-			-			-			-			(603,626	)		(603,626	)
Foreign currency translation		-			-			-			-			-			3,445			-			3,445
Total Comprehensive loss																							(600,181	)
Balance, December 31, 2012		110,276,978			110,277			-			-			25,828,544			(8,898	)		(14,405,140	)		11,524,783
Issued for services		156,343			156			-			-			59,844			-			-			60,000
Comprehensive income
Net loss		-			-			-			-			-			-			(542,268	)		(542,268	)
Foreign currency translation		-			-			-			-			-			6,497			-			6,497
Total Comprehensive loss																							(535,771	)
Balance, December 31, 2013		110,433,321		$	110,433			-		$	-		$	25,888,388		$	(2,401	)	$	(14,947,408	)	$	11,049,012

27

HOLLOMAN ENERGY CORPORATION

(An Exploration Stage Company)

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1.  NATURE AND CONTINUANCE OF OPERATIONS

Holloman Energy Corporation (the “Company”), was incorporated in the State of Nevada on May 14, 2004. The Company focuses on oil and gas exploration and development in Australia’s Cooper Basin.

The Company’s consolidated financial statements are prepared on a going concern basis in accordance with generally accepted accounting principles in the United States (“US GAAP”) which contemplates the realization of assets and discharge of liabilities and commitments in the normal course of business. The Company is in the exploration stage. It has not generated operating revenues, and has accumulated losses of $14,947,408 since inception. The Company has funded its operations through the issuance of capital stock, joint venturing of its work program obligations with third parties who have paid a significant portion of required program costs, and debt. Management plans to raise additional funds through: third-party equity or debt financings, continued joint venturing of its work program obligations, and reliance upon the continued support of its controlling shareholder. There is no certainty that further funding will be available as needed. These factors raise substantial doubt about the ability of the Company to continue operating as a going concern. The Company’s ability to continue its operations as a going concern, realize the carrying value of its assets, and discharge its liabilities in the normal course of business is dependent upon: the continued participation of its joint venture partners and the support of its controlling shareholder, its ability to raise capital sufficient to fund its commitments and ongoing losses, and ultimately generating profitable operations.

2.  SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

These consolidated financial statements and related notes are presented in accordance with US GAAP, and are expressed in United States dollars. The Company has not produced revenues from its principal business and is an exploration stage company as defined by Financial Accounting Standards Board (FASB) Accounting Standards Codification (“ASC”) Topic 915, Development Stage Entities. These statements include the accounts of the Company and its wholly owned subsidiaries First Endeavor Holdings, Inc. (“FEH”) and Holloman Petroleum Pty. Ltd. (“Holloman Petroleum”). All intercompany transactions and balances have been eliminated.

Use of Estimates

The preparation of financial statements in conformity with US GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company regularly evaluates estimates and assumptions. The Company bases its estimates and assumptions on current facts, historical experience and various other factors it believes to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities and the accrual of costs and expenses that are not readily apparent from other sources. The actual results experienced by the Company may differ materially and adversely from the Company’s estimates. To the extent there are material differences between the estimates and the actual results, future results of operations will be affected. The most significant estimates with regard to these consolidated financial statements relate to carrying values of oil and gas properties, determination of fair values of stock based transactions, and deferred income tax rates.

Foreign Currency Translation

The Company and its Australian subsidiaries’ functional and reporting currency is the United States dollar. The functional currency of the Company’s Canadian subsidiary (which is currently inactive) is the Canadian dollar. Foreign currency financial statements of the Company’s Canadian subsidiary are translated to United States dollars using period-end rates of exchange for assets and liabilities, and average rates of exchange for the period for revenues and expenses. Translation gains (losses) are recorded in accumulated other comprehensive income as a component of stockholders’ equity. Foreign currency financial statements of the Company’s Australian subsidiaries use period end rates for monetary assets and liabilities, historical rates for historical cost balances, and average rates for expenses.  If material, translation gains and losses are included in the determination of income. Foreign currency transactions of the Company’s subsidiaries are primarily undertaken in Australian and Canadian dollars. The Company has not, to the date of these consolidated financial statements, entered into derivative instruments to offset the impact of foreign currency fluctuations.

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Fair Market Measurements

The Company estimates the fair values of financial and non-financial assets and liabilities under ASC Topic 820 “Fair Value Measurements and Disclosures” (“ASC Topic 820”). ASC Topic 820 provides a framework for consistent measurement of fair value for those assets and liabilities already measured at fair value under other accounting pronouncements. Certain specific fair value measurements, such as those related to share-based compensation, are not included in the scope of ASC Topic 820. Primarily, ASC Topic 820 is applicable to assets and liabilities related to financial instruments, to some long-term investments and liabilities, to initial valuations of assets and liabilities acquired in a business combination, and to long-lived assets written down to fair value when they are impaired. It does not apply to oil and natural gas properties accounted for under the full cost method, which are subject to impairment based on SEC rules. ASC Topic 820 applies to assets and liabilities carried at fair value on the consolidated balance sheet, as well as to supplemental fair value information about financial instruments not carried at fair value.

Valuation techniques are generally classified into three categories: the market approach; the income approach; and the cost approach. The selection and application of one or more of these techniques requires significant judgment and is primarily dependent upon the characteristics of the asset or liability, the principal (or most advantageous) market in which participants would transact for the asset or liability and the quality and availability of inputs. Inputs to valuation techniques are classified as either observable or unobservable within the following hierarchy:

● Level 1 — quoted prices in active markets for identical assets or liabilities.

● Level 2 — inputs other than quoted prices that are observable for an asset or liability. These include: quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; inputs other than quoted prices that are observable for the asset or liability; and inputs that are derived principally from or corroborated by observable market data by correlation or other means (market-corroborated inputs).

● Level 3 — unobservable inputs that reflect the Company’s own expectations about the assumptions that market participants would use in measuring the fair value of an asset or liability.

A financial instrument’s level within the fair value hierarchy is based on the lowest level of any input that is significant to the fair value measurement.

Where available, fair value is based on observable market prices or parameters or derived from such prices or parameters. Where observable prices or inputs are not available, valuation models are applied. These valuation techniques involve some level of management estimation and judgment, the degree of which is dependent on the price transparency for the instruments or market and the instrument’s complexity.

Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis

Acquired oil and gas properties are reported at fair value on a nonrecurring basis in the Company’s balance sheet. See Oil and Gas Properties below for further discussion of the methods and assumptions used to estimate fair values.

Cash, Cash Equivalents and the Fair Value of Financial Instruments

The Company considers all highly liquid instruments with an original maturity of three months or less at the time of issuance to be cash equivalents. Cash and cash equivalents totaled $23,260 and $1,009,882 at December 31, 2013 and 2012, respectively. The Company is exposed to a concentration of credit risk with respect to its cash deposits. The Company places cash deposits with highly rated financial institutions in the United States and Australia. At times, cash balances held in financial institutions may be in excess of insured limits. The Company believes the financial institutions are financially strong and the risk of loss is minimal. The Company has not experienced any losses with respect to the related risks and does not believe its exposure to such risks is more than normal.

The estimated fair values for financial instruments are determined at discrete points in time based on relevant market information. These estimates involve uncertainties and cannot be determined with precision. The estimated fair value of cash, other receivables, accounts payable, accrued liabilities and demand notes payable approximates their carrying value due to their short-term nature.

Long-Lived Assets

The carrying value of long-lived assets is reviewed on a regular basis for the existence of facts or circumstances that may suggest impairment. The Company recognizes impairment when the sum of the expected undiscounted future cash flows is less than the carrying amount of the asset. Impairment losses, if any, are measured as the excess of the carrying amount of the asset over its estimated fair value.

Oil and Gas Properties

The Company utilizes the full cost method to account for its investment in oil and gas properties. Accordingly, all costs associated with acquisition, exploration and development of oil and gas reserves, including such costs as leasehold acquisition costs, interest costs relating to unproved properties, geological expenditures, tangible and intangible development costs including direct internal costs are capitalized to the full cost pool. When the Company commences production from established proven oil and gas reserves, capitalized costs, including estimated future costs to develop the reserves and estimated abandonment costs, net of salvage, will be depleted on the units-of-production method using estimates of proved reserves. Costs of unproved properties are not amortized until the proved reserves associated with the projects can be determined or until impairment occurs. If an assessment of such properties indicates that properties are impaired, the amount of impairment is added to the capitalized cost base to be amortized. At December 31, 2013 and 2012, the Company assessed that there was no material impairment of unproved properties.

29

The capitalized costs included in the full cost pool are subject to a "ceiling test" (based on 12-month average of first-day-of-the-month pricing), which limits such costs to the aggregate of the (i) estimated present value, using a ten percent discount rate, of the future net revenues from proved reserves, based on current economic and operating conditions, (ii) the lower of cost or estimated fair value of unproven properties included in the costs being amortized, (iii) the cost of properties not being amortized, less (iv) income tax effects related to differences between the book and tax basis of the cost of properties not being amortized and the cost or estimated fair value of unproved properties included in the costs being amortized. At December 31, 2013, all of the Company’s oil and gas interests were classified as unproven properties and were not being amortized.

Sales of proved and unproved properties are accounted for as adjustments of capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between capitalized costs and proved reserves of oil and gas, in which case the gain or loss is recognized in the statement of operations.

Asset Retirement Obligations

The Company records the fair value of an asset retirement obligation as a liability in the period in which it incurs an obligation associated with the retirement of tangible long-lived assets that result from the acquisition, construction, development and/or normal use of the assets. The estimated fair value of the asset retirement obligation is based on the current cost escalated at an inflation rate and discounted at a credit adjusted risk-free rate. This liability is capitalized as part of the cost of the related asset and amortized over its useful life. The liability accretes until the Company settles the obligation.

Environmental

Oil and gas activities are subject to extensive federal and provincial environmental laws and regulations. These laws, which are constantly changing, regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites.

Environmental expenditures are expensed or capitalized depending on their future economic benefit. Expenditures that relate to an existing condition caused by past operations and that have no future economic benefits are expensed. Expenditures that have future economic benefits are capitalized. Liabilities for expenditures of a non-capital nature are recorded when an environmental assessment and/or remediation is probable, and the costs can be reasonably estimated.

Income Taxes

Income taxes are determined using the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using the enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes that date of enactment. In addition, a valuation allowance is established to reduce any deferred tax asset for which it is determined that it is more likely than not that some portion of the deferred tax asset will not be realized.

The Company accounts for uncertainty in income taxes by applying a two-step method. First, it evaluates whether a tax position has met a more likely than not recognition threshold, and second, it measures that tax position to determine the amount of benefit, if any, to be recognized in the financial statements. The application of this method did not have a material effect on the Company's consolidated financial statements.

Stock Based Compensation

The Company records compensation expense in the consolidated financial statements for share based payments using the fair value method. The fair value of stock options granted to directors and employees is determined using the Black-Scholes option valuation model at the time of grant. Fair value for common shares issued for goods or services rendered by non-employees are measured based on the fair value of the goods and services received. Share-based compensation is expensed with a corresponding increase to share capital. Upon the exercise of the stock options, the consideration paid is recorded as an increase in share capital.

Other Comprehensive Income (Loss)

The Company reports and displays comprehensive income and loss and its components in the consolidated financial statements. For the years ended December 31, 2013 and 2012, the only components of comprehensive loss were foreign currency translation adjustments.

30

Earnings Per Share

The Company presents both basic and diluted earnings per share (“EPS”) on the face of the consolidated statements of operations. Basic EPS is computed by dividing net earnings (loss) available to common shareholders by the weighted average number of shares outstanding during the period. Diluted EPS gives effect to all dilutive potential common shares outstanding during the period including convertible debt, stock options, and warrants, using the treasury stock method. Diluted EPS excludes all dilutive potential shares if their effect is anti-dilutive. Diluted EPS figures are equal to those of Basic EPS for each period since we had no securities outstanding during periods in which the Company generated net income that were potentially dilutive.

Recent Accounting Pronouncements

The Company has reviewed recently issued accounting pronouncements and plans to adopt those that are applicable to it. It does not expect the adoption of these pronouncements to have a material impact on its consolidated financial position, results of operations or cash flows.

3.  DIVESTITURE OF ENDEAVOR AND DISCONTINUED OPERATIONS

Effective August 3, 2007, the Company entered into a share exchange agreement to acquire 100% of the issued and outstanding shares of Endeavor Canada Corporation (“Endeavor”), an Alberta Canada corporation involved in oil and gas development. The Company’s acquisition of Endeavor was accounted for as a re-capitalization using accounting principles applicable to reverse acquisitions whereby the financial statements subsequent to the date of the transaction are presented as a continuation of Endeavor. Under re-capitalization accounting Endeavor was treated as the Company’s accounting parent (legal subsidiary) and the Company was treated as the accounting subsidiary (legal parent). Accordingly, the consolidated results of operations of the Company include those of Endeavor from its inception on May 5, 2006 and those of the Company from the closing date of the re-capitalization on August 3, 2007. Endeavor, the acquired entity, was regarded as the predecessor and continuing entity as of August 3, 2007.

On February 1, 2008, the Company entered into an agreement with its former Chief Executive Officer which provided the Company the option of exchanging all of its interest in Endeavor. On February 15, 2008, the option was exercised. In exchange, all outstanding shares of Endeavor were transferred to the former CEO. The Company recognized a gain on its divestiture of Endeavor as follows:

Net liabilities of Endeavor:
Assets	$	(780,467	)
Liabilities, including $351,504 in amounts payable to related parties		3,401,781
Accumulated comprehensive income		(31,265	)
Carrying value		2,590,049
Share consideration received		6,507
Intercompany receivables written off		(1,812,688	)
Gain on disposal of discontinued operations	$	783,868

4.  OIL AND GAS PROPERTIES

General

All of the Company’s oil and gas properties are located in Australia and are unproven. As such, the costs capitalized in connection with those properties are not currently subject to depletion. The costs incurred in oil and gas property acquisition and exploration activities are summarized as follows:

Australian Exploration Properties - Unproven
Balance, December 31, 2006	$	––
Acquisition costs		15,903,000
Impact of deferred tax liability		6,177,000
Exploration costs		290,925
Balance, December 31, 2007		22,370,925
Exploration Costs		710,204
Balance, December 31, 2008		23,081,129
Write down – Barrow		(2,908,010	)
Write down – Vic P60		(2,212,197	)
Write down – Deferred tax gross-ups		(1,636,508	)
Exploration Costs		131,806
Balance, December 31, 2009		16,456,220
Exploration Costs		174,571
Balance, December 31, 2010		16,630,791
Exploration Costs		4,144
Balance, December 31, 2011		16,634,935
Exploration Costs - Recovered		(5,773	)
Balance, December 31, 2012		16,629,162
Exploration Costs		556,456
Balance, December 31, 2013	$	17,185,618

31

Offshore – The Gippsland and Barrow Basins

In May 2007, the Company entered into an agreement to acquire a 62.5% working interest in an Australian oil and gas exploration permit (“Vic P60”) covering 340,000 acres, more or less, in the Gippsland Basin in Australia. On November 21, 2007, the Company purchased seven Australian oil and gas permits. This purchase was facilitated by the acquisition of Holloman Petroleum, a privately held Australian-based company, for 18,600,000 shares of the Company's common stock with a fair market value of $15,903,000. The purchase included a 66.67% working interest in three licenses located in the Cooper Basin in the State of South Australia, the remaining 37.5% working interest in Vic P60 and a 100% working interest in three permits in the Barrow Sub-Basin in the State of Western Australia. During 2009, the Company relinquished its Barrow Sub-Basin and Vic P60 permits, and recognized a net loss on the impairment of oil and gas assets of $5,759,694. This loss included the write-off of a $639,487 deposit paid in connection with the acquisition of Vic P60. The carrying value of oil and gas properties was also reduced by $1,636,508 in deferred tax gross-ups relating to the relinquished permits.

Onshore – The Cooper Basin

At December 31, 2013, the Company holds working interests in two onshore Petroleum Exploration Licenses (PELs) in Australia. PEL 112, in which the Company holds a 48.5007% working interest, is comprised of 2,196 square kilometers (542,643 gross acres, 263,185 net acres). PEL 444, in which the Company holds a 66.667% working interest, is comprised of 2,358 square kilometers (582,674 gross acres, 388,451 net acres). Both licenses are located on the southwestern flank of the Cooper Basin in the State of South Australia. The Company’s oil and gas properties are unproven. As such, the costs capitalized in connection with those properties are not currently subject to depletion.

Subsequent to December 31, 2013 the Company renewed its license on PEL 112 and relinquished a portion of its acreage. The Company believes the acreage relinquished was non-prospective. The Company also granted an additional working interest in PEL 444 to a joint venture partner in connection with the Terra Nova Farm-In Agreement (see Note 12).

The Terra Nova Farm-In Agreement

Effective May 11, 2012, the Company entered into a definitive Oil and Gas Farm-In Agreement with Terra Nova Energy Ltd., and its wholly owned subsidiary Terra Nova Resources Inc. (“Terra Nova”), Australian-Canadian Oil Royalties Ltd. (“ACOR”) and Eli Sakhai (“Sakhai”) on PEL 112 and PEL 444 (the “Agreement”). The Agreement provides terms under which Terra Nova may earn up to a 55% undivided working interest in PEL 112 and PEL 444 (the “Farm-In Interest”).

During 2012, in connection with the Agreement, Terra Nova paid the Company non-refundable cash fees totaling $350,000, and 666,670 shares of its common stock with a fair market value of $193,334. The shares were measured at fair market value on a non-recurring basis using quoted market prices, and are categorized as a Level 1 fair value measurement under ASC Topic 820. The Company agreed to provide ACOR and Sakhai a full accounting of its use of the cash fees, and to share with ACOR and Sakhai, any excess of the cash fees over the transaction costs it incurred in connection with the Agreement. As a result of its analysis, the Company identified a total of $54,719 in excess fees to be refunded to ACOR and Sakhai. Of that amount, the Company withheld $37,340 as a recovery of exploration costs payable to it by ACOR and Sakhai.

To earn the entire Farm-In Interest, Terra Nova is required to fund exploration and development expenditures (the “Earning Obligations”) totaling at least AUD$13,700,000 (USD$14,308,000) including:

●   AUD$4,700,000 (USD$4,968,000) which was placed in escrow during May 2012 for use in the completion of a seismic acquisition program sufficient to meet the minimum seismic acquisition requirements and interpretation of the acquired data for PEL 112 and PEL 444 (earning a 20% working interest in each license upon completion of the seismic obligations);

●   AUD$4,500,000 (USD$4,670,000) which was placed in escrow on November 1, 2012 to secure Terra Nova’s obligation to sole fund the dry-hole costs of an initial three (3) well drilling program on either PEL 112 or PEL 444, provided that at least one well is drilled on each license (earning a working interest of 5.833% per well in each license upon completion, totaling a working interest of 17.5%); and

●   AUD$4,500,000 (USD$4,670,000) to be placed in escrow on or before 45 days following completion or abandonment of the third well in the initial well program for use in funding the first AUD$4,500,000 in dry-hole costs of an optional three (3) well drilling program on either PEL 112 or PEL 444, provided that at least one well is drilled on each license (earning a working interest of 5.833% per well in each license upon completion, totaling a working interest of 17.5%).

Terra Nova acts as contract operator with respect to all seismic acquisition and drilling work contemplated by the Agreement.

Effective May 29, 2013, the Agreement was amended such that of the AUD$4,500,000 (USD$4,670,000) placed in escrow for the Initial Well Program, AUD$500,000 (USD$482,250) was used to pay costs incurred in the PEL 444 seismic program. Costs incurred in relation to the seismic earning obligations in excess of AUD$5,200,000 (previously AUD$4,700,000), have been borne by Terra Nova, the Company, ACOR and Sakhai in accordance with their working interest percentages calculated as though Terra Nova had successfully completed its Earning Obligations and earned the entire Farm-In Interest.

In July 2013, Terra Nova drilled the first well on PEL 112. The well was plugged and abandoned in August 2013. In the event Terra Nova elects to complete the second well drilled in connection with the initial three well drilling program, Terra Nova will pay 50% of the completion costs and the Company will pay the other 50% of the completion costs. In the event Terra Nova elects to complete the third well drilled in connection with the initial three well drilling program, or any well drilled in connection with the optional three well drilling program, Terra Nova will pay 50% of the completion costs, and the Company, ACOR and Sakhai will pay the other 50% of the completion costs in accordance with their working interest at the effective date of the Agreement.

32

In the event any well drilled in connection with either the initial or optional drilling programs is commercially viable, and Terra Nova elects to complete such well, Terra Nova is entitled to a preferential recovery of one hundred percent of the costs it has paid to drill and test that successful well. Terra Nova is entitled to 80% of production from that successful well until either that successful well has ceased production or Terra Nova has received net revenue equal to the reimbursable costs it has incurred.

Terra Nova earns the Farm-In Interest in stages based upon successful completion of specific Earning Obligations. In each instance, the Company, ACOR and Sakhai will each contribute a portion of the working interest earned by Terra Nova. In the event Terra Nova earns the entire Farm-In Interest, the Company, ACOR and Sakhai will transfer to Terra Nova the following working interest percentages in both PEL 112 and PEL 444:

(a)   The Company will contribute an undivided 38.556% working interest in both PEL 112 and PEL 444 (resulting in a residual working interest position of 28.112% in each license);

(b)   ACOR will contribute an undivided 8.222% working interest in both PEL 112 and PEL 444; and

(c)   Sakhai will contribute an undivided 8.222% working interest in both PEL 112 and PEL 444.

The Agreement may be terminated by any party upon the occurrence of an uncured breach of any material term. Terra Nova may terminate the Agreement any time before it has earned the Farm-In Interest upon providing written notice of such termination. In the event Terra Nova terminates the Agreement, it shall not be entitled to any interest in either PEL 112 or PEL 444 unless it has satisfied an Earning Obligation with respect to that license.

Cooper Basin Exploration Activity

Acquisition of 127 square kilometers of 3D seismic data on PEL 112 (the “Mulka Survey”) was completed in late September 2012. The Mulka Survey fulfilled the Company’s minimum work requirements for PEL 112 License Year Four. As a result, Terra Nova completed its seismic Earning Obligation with respect to PEL 112, and earned an undivided 20% working interest in that license. Geokinetics (Australia) Pty. Ltd. undertook the Mulka Survey on the northern boundary of PEL 112 under the direction of Terra Nova. The Company, ACOR and Sakhai each contributed the following portion of the working interest earned to Terra Nova:

(a)   The Company contributed an undivided 13.3334% working interest in PEL 112 resulting in a residual working interest position of 53.334% in that license;

(b)   ACOR contributed an undivided 3.3333% working interest in PEL 112; and

(c)   Sakhai contributed an undivided 3.3333% working interest in PEL 112.

On July 17, 2013, the Government of South Australia finalized and registered the transfer of the 20% working interest earned by Terra Nova in PEL 112.

On July 23, 2013, the Company spudded the Wolfman #1 exploration well on PEL 112. The well’s primary oil objective, the Namur Sandstone, was encountered at approximately 1,197 meters (3,927 feet) on August 6, 2013. Drilling continued to its secondary targets in the Birkhead formation and Hutton sandstones. Wolfman #1 reached Total Depth of 1,703 meters (5,587 feet), on August 7, 2013. No oil shows were observed while drilling in the primary and secondary oil objectives, and the well was plugged and abandoned. The entire cost of the well was paid by Terra Nova in accordance with the terms of the Agreement. The drilling of Wolfman #1 fulfilled the Company’s minimum work requirement for PEL 112 License Year Five.

Upon completion of Wolfman #1 Terra Nova earned an additional undivided 5.8333% working interest in PEL 112. The Company, ACOR and Sakhai each contributed the following portion of the working interest earned to Terra Nova:

(a)   The Company contributed an undivided 4.8333% working interest in PEL 112 resulting in a residual working interest position of 48.5007% in that license;

(b)   ACOR contributed an undivided 0.5000% working interest in PEL 112; and

(c)   Sakhai contributed an undivided 0.5000% working interest in PEL 112.

On December 20, 2013, the Government of South Australia registered the transfer of the 5.8333% working interest earned by Terra Nova in PEL 112.

During November 2013, the Company applied for a five-year renewal of its license on PEL 112. In connection with its application, the Company offered to relinquish 1,110 square kilometers (274,287 acres) of the area covered by that license. The Company’s management believes the acreage to be relinquished is non-prospective. On December 18, 2013, the Government of South Australia accepted the Company’s application and offered to renew its license on PEL 112.

Subsequent to December 31, 2013, the renewal of the Company’s license on PEL 112 was finalized (see Note 12). The Company intends to continue development of the remaining prospects identified on that concession.

Acquisition of 80 square kilometers of 3D seismic data on PEL 444 (the “Wingman Survey”) began May 28, 2013 and was completed on July 2, 2013. At December 31, 2013, the processing of seismic data from the Wingman Survey was complete and the Company was awaiting interpretation of that data. The completion of the Wingman Survey fulfills the Company’s minimum work requirements for PEL 444 License Year Three. Subsequent to December 31, 2013, Terra Nova finalized its interpretation of the Wingman Survey data and earned a 25.8333% working interest in PEL 444 (see Note 12).

5. NOTE PAYABLE

On December 24, 2012, the Company entered into a Promissory Note with an unrelated party (“Lender”) under which it borrowed the principal amount of $1,000,000 (the “Note”). The Note bears interest at 4.5% per annum and provides for a penalty rate of interest of 10% per year on any unpaid principal which is not paid when due. The Note is payable upon demand of the Lender at any time, and may be prepaid by the Company without notice or penalty and has therefore been classified as a current liability. On August 16, 2013, the Company voluntarily repaid $60,000 of principal on the Note, as a result, at December 31, 2013, the principal balance of the Note was $940,000.

For the years ended December 31, 2013 and 2012, the Company recognized $43,979 and $740, respectively in interest expense on the Note, $10,662 of interest incurred remained unpaid at December 31, 2013.

The Company’s controlling shareholder guaranteed the Company’s obligations under the Note.

Subsequent to December 31, 2013, the Company initiated a transaction in which the remaining principal balance of the Note will be exchanged by the Lender for a 1% overriding royalty interest in all production of oil, gas and associated hydrocarbons from PEL 112 and PEL 444 (see Note 12).

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6. OTHER INCOME

During the year ended December 31, 2012, in connection with the Agreement, Terra Nova paid the Company cash fees totaling $350,000, and 666,670 shares of its common stock with a fair market value of $193,334 (see Note 4). All fees paid by Terra Nova were fully earned upon receipt, and were not repayable to Terra Nova under any circumstances. After an offset of $54,719 in amounts refunded to ACOR and Sakhai, the Company recognized other income relating to these fees of $488,615.

On July 29, 2011, the Company entered into an oil and gas farm-in agreement with Brandenburg Energy Corp., ("Brandenburg"). In connection with this agreement, Brandenburg paid the Company $261,212 in contract advances. On February 27, 2012, the Company terminated its agreement with Brandenburg.Upon execution of the agreement with Brandenburg, $261,212 in contract payments became non-refundable. Of that amount $40,094, which had been incurred on contract related expenditures during the three months ended June 30, 2011, were recognized as other income during the year ended December 31, 2011. The remaining balance of $7,160 was recognized as other income during the year ended December 31, 2012.

7.  RELATED PARTY TRANSACTIONS

On December 24, 2012, the Company’s controlling shareholder guaranteed the Company’s obligations under a note payable in the principal amount of $1,000,000 (see Note 5).

On April 2, 2012, the Company’s Board of Directors consented to the distribution of 666,670 shares of the common stock of Terra Nova, to its directors, officers and principal advisors. The Terra Nova shares were received by the Company in connection with the Agreement with Terra Nova, and were distributed as compensation for efforts put forth in securing the Terra Nova opportunity. The fair market value of the Terra Nova shares is the market price of the shares at the date they were earned by the Company. The 666,670 shares had an aggregate value of $193,334, or $0.29 per share at that date.

On April 2, 2012, the Company granted 1,000,000 shares of its common stock to a consultant whose efforts it judged instrumental in identifying and finalizing the Agreement with Terra Nova (see Note 10).

On March 1, 2012, the Company executed a promissory note in the principal amount of $100,000 with one of its consultants who is also a shareholder. The note was non-interest bearing and payable upon demand. The entire principal amount of the note was repaid on March 23, 2012.

During 2013, management fees totaling $118,028 (2012 - $111,525) were paid to the Company’s Chief Financial Officer. The fees were incurred as compensation for services rendered in the normal course of operations and were paid at the amount established and agreed to by the related parties.

Effective October 1, 2010, the Company executed an administrative services agreement with Holloman Corporation, the Company’s controlling shareholder. Under this agreement, fees of $5,000 per month are payable to Holloman Corporation covering office and meeting space, supplies, utilities, office equipment, network access and other administrative facilities costs. These fees are payable quarterly in shares of the Company’s restricted common stock at the closing price of the stock on the last trading-day of the applicable monthly billing period. This administrative services agreement can be terminated by either party with 30-days’ notice. During 2013, the Company recorded $60,000 (2012 – $60,000) of office expense and issued 156,343 (2012– 204,379) shares of its common stock as a result of this agreement (see Note 10).

8.  STOCK-BASED COMPENSATION

On August 15, 2009, the Company established a Non-Qualified Stock Option Plan and a Stock Bonus Plan. The Non-Qualified Stock Option Plan (the “Option Plan”) authorizes the issuance of up to 7,200,000 shares of the Company’s common stock. Under the Stock Bonus Plan up to 300,000 shares (“Bonus Shares”) of the Company’s common stock may be issued to employees, directors, officers, consultants and advisors, provided qualifying services are rendered.

At the discretion of the Company’s Board of Directors, any option may include installment exercise terms such that the option becomes fully exercisable in a series of cumulating portions. Any options granted or shares issued pursuant to the Plans will be forfeited if the "vesting" schedule established at the time of the grant is not met. The Company may at any time, and from time to time, amend, terminate, or suspend one or more of the Plans in any manner its deems appropriate, provided that any amendment, termination or suspension may not adversely affect rights or obligations with respect to options or shares previously granted.

Issuance of Options and Bonus Shares

On April 3, 2012, the Company granted options to its Chief Executive Officer under the terms shown below. The options were granted pursuant to the Option Plan.

Number of Shares Issuable Upon Exercise of Option		Exercise Price		First Date Exercisable	Expiration Date
	450,000	$	0.70	4/3/2012	8/15/2012
	450,000	$	0.80	4/3/2012	8/15/2012
	450,000	$	1.00	4/3/2012	8/15/2014
	450,000	$	1.20	4/3/2012	8/15/2014
	1,800,000

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The Company applied the Black-Scholes option pricing model to determine the fair market value of the options granted. In applying the model, the Company used the following parameters: contractual lives of .38 to 2.38 years, historical stock price volatility of 103% to 138%, a risk-free rate of 4.5% and an annual dividend rate of 0%. As a result, the Company determined that the total fair market value of the options granted was $104,874 and the weighted-average grant-date fair value per option granted was $0.06.

On February 14, 2012, stock warrants providing for the purchase of 700,003 shares of the Company’s common stock, at a price of $0.25 per share, expired without exercise. On August 15, 2012, stock options granted in connection with the Company’s 2009 Non-Qualified Stock Option Plan providing for the purchase of 3,300,000 shares of the Company’s common stock, at a weighted average price of $0.75 per share expired without exercise. At December 31, 2013 the Company had a total of 3,300,000 stock options outstanding with weighted average exercise prices and lives of $1.10 and 8.5 months, respectively.

A summary of Option Plan activity as of December 31, 2013, and changes during the year then ended is presented below.

Options	Shares (000’s)		Weighted-Average Exercise Price		Weighted-Average Remaining Contract Term (yrs)		Aggregate Intrinsic value
Outstanding – January 1, 2013		3,300	$	1.10
Granted		––		––
Exercised		––		––
Forfeited or expired		––		––
Outstanding – December 31, 2013		3,300	$	1.10		0.71	$	0.00
Exercisable – December 31, 2013		3,300	$	1.10		0.71	$	0.00

There was no share-based compensation recognized during the year ended December 31, 2013.

A total of $104,874 in non-cash, stock-based compensation was recognized in connection with the Option Plan during the year ended December 31, 2012.

In addition, on April 3, 2012, the Company authorized the issuance of 75,000 bonus shares of its common stock pursuant to the 2009 Stock Bonus Plan. The fair market value of these bonus shares is the market price of the shares at the date of grant. The 75,000 bonus shares had an aggregate value of $21,750, or $0.29 per share at that date.

On April 3, 2012, the Company also issued its Chief Executive Officer fractional participation in a 2% net revenue interest in wells drilled by the Company on PEL 112 and PEL 444. The participation units granted represent a 0.017% interest in the Company’s Cooper Basin revenues, after all royalties, exploration expenses, operating costs and capital investments associated with the Cooper Basin have been recovered. In management’s opinion no value can be assigned to these revenue interests, as any valuation is non-estimable.

9.  PREFERRED SHARES

The Company and its wholly-owned subsidiary, First Endeavor Holdings (“FEH”), are each authorized to issue 10,000,000 preferred shares with a par value of $0.001 per share. At December 31, 2013 and 2012, neither the Company nor FEH had any preferred shares outstanding.

10.  COMMON SHARES

The Company is authorized to issue 150,000,000 common shares with a par value of $0.001.

On April 2, 2012, the Company granted 1,000,000 shares of its common stock to a consultant whose efforts it judged instrumental in identifying and finalizing the Agreement with Terra Nova. The grant was conditioned upon the execution of the Agreement which occurred on May 11, 2012. The 1,000,000 bonus shares had a fair market value at the date of grant equal to $290,000, or $0.29 per share.

During 2013, the Company issued 156,343 (2012 – 204,379) shares of common stock, at an average price of $0.384 (2012 - $0.294) per share in connection with the conversion of $60,000 (2012 - $60,000) in administrative service fees payable to its controlling shareholder.

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11.  INCOME TAXES

The Company is subject to United States federal income taxes at an approximate rate of 35%. The reconciliation of the provision for income taxes at the United States federal statutory rate compared to the Company’s income tax expense as reported is as follows:

		Year Ended December 31, 2013		Year Ended December 31, 2012
Statutory tax rates		35	%		35	%
Expected recovery of income taxes at statutory rates	$	103,182		$	(214,506	)
Increase (reduction) in income taxes resulting from:
Non-deductible expenditures and other		-			34,282
Foreign exchange rate and tax rate differences		(220,870	)		27,917
Valuation allowance change		946,263			152,307
Provision for income taxes	$	828,575		$	––

The significant components of deferred income tax assets and liabilities at December 31, 2013 and 2012 are as follows:

	Year Ended December 31, 2013			Year Ended December 31, 2012
Deferred income tax assets:
Stock-based compensation	$	878,925		$	878,925
US net operating loss carryforwards		1,509,626			1,353,256
Australian operating loss carryforwards		814,822			277,616
Australian deposits on property		––			––
US loan receivable		543,806			543,806
Other accruals		17,536			16,889
Total deferred income tax assets		3,764,715			3,070,492
Less: valuation allowance		(3,764,715	)		(2,818,452	)
Deferred income tax assets, net		-			252,040
Petroleum and natural gas properties, Australia		(4,992,436	)		(5,161,657	)
Deferred income tax liabilities, net	$	(4,992,436	)	$	(4,909,617	)

In the United States, the Company had regular tax net operating losses of $4,313,217 that expire from 2026-2036. A valuation allowance of $2,406,087 has been applied against the deferred tax assets.

In Australia, the Company had regular tax net operating losses of $2,716,074 that may be used in future years to reduce taxable income. A valuation allowance of $1,358,629 has been applied against the deferred tax assets.

The Company's tax returns for 2010 and subsequent years remain subject to examination by tax authorities.

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12.  SUBSEQUENT EVENTS

During November 2013, the Company applied for a five-year renewal of its license on PEL 112. On December 18, 2013, the Government of South Australia accepted the Company’s application and offered to renew its license on PEL 112 in accordance with its terms. On March 12, 2014, the Government of South Australia finalized its renewal of PEL 112. As a result, the Company now holds a 48.5007% working interest in PEL 112 comprising 1,086 square kilometers  (268,356 acres) until January 10, 2019.

During February 2014, Terra Nova finalized its interpretation of the Wingman Survey data and earned a 25.8333% working interest in PEL 444. The working interest earned by Terra Nova was comprised of a 20% interest resulting from the completion of the Wingman Survey and a 5.8333% interest granted in connection with Terra Nova’s completion of the Wolfman #1 well. The Company, ACOR and Sakhai each contributed a portion of the working interest earned by Terra Nova as follows:

(d)   The Company contributed an undivided 18.1667% working interest in PEL 444 resulting in a residual working interest position of 48.5007% in that license;

(e)   ACOR contributed an undivided 3.8333% working interest in PEL 444; and

(f)   Sakhai contributed an undivided 3.8333% working interest in PEL 444.

As of March 28, 2014 the Government of South Australia was processing the documents required to finalize the transfer of the working interest earned by Terra Nova.

On February 24, 2014, the Company initiated a non-binding transaction in which it has agreed to assign a 1% overriding royalty interest in all production of oil, gas and associated hydrocarbons arising from lands covered by PEL 112 and PEL 444 in exchange for $940,000, which is the remaining principal balance of its Note payable to a third party (see Note 5). The completion of the transaction is contingent upon the rejection of first rights of refusal by Terra Nova, ACOR and Sakhai.

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SIGNATURES

In accordance with Section 13 or 15(d) of the Exchange Act, the registrant caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	HOLLOMAN ENERGY CORPORATION
March 28, 2014	By:	/s/ Mark Stevenson
		Mark Stevenson
		President and Principal Executive Officer

In accordance with the Securities Exchange Act, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Signature	Date
/s/ Mark Stevenson	March 28, 2014
Mark Stevenson, Principal Executive Officer and Director
/s/ Robert Wesolek	March 28, 2014
Robert Wesolek, Principal Financial  and Accounting Officer
/s/ J. Douglas Brown	March 28, 2014
J. Douglas Brown, Director
/s/ Eric Prim	March 28, 2014
Eric Prim, Director
/s/ Keith Macdonald	March 28, 2014
Keith Macdonald, Director

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