10-K/A 1 nce10ka123109.htm NEW CONCEPT ENERGY, INC.

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K/A
(Amendment No. 1)
(Mark One)

[X] | ANNUAL REPORT PURSUANT TO SECTION 13 OR 5(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the Year ended December 31, 2009

| OR

[ ] | 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 000-08187

NEW CONCEPT ENERGY, INC.

(Exact name of registrant as specified in its charter)

Nevada |  | 75-2399477
(State or other jurisdiction of Incorporation or organization) |  | (IRS Employer Identification Number)
| 1800 Valley View Lane,Suite 300 Dallas, Texas |
| (Address of principal executive offices) |
| 75234 |
| (Zip Code) |
| Registrant’s Telephone Number, including area code |
| (972) 407-8400 |

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class |  | Name of each exchange on which registered
Common Stock, $0.01 par value |  | American Stock Exchange

Securities registered pursuant to Section 12(g) of the Act: None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes [ ] No [X]
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes [ ] No [X]
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes [X] No [ ]
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website if any, every interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months(or for such shorter period that the registrant was required to submit and post such files) Yes [ ] No [ ]
Indicate by check mark 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 registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. [X]
Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act). Yes [ ] No [X]
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act. Yes [ ] No [X]
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a non-accelerated filer, or a smaller reporting company. See definition of “large accelerated filer,” ”accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer | ______ | Accelerated filer | ______
Non-accelerated filer | ______ | Smaller reporting company | __X___

The aggregate market value of the shares of voting and non-voting common equity held by non-affiliates of the Registrant, computed by reference to the closing price at which the common equity was last sold which was the sales price of the Common Stock on the American Stock Exchange as of June 30, 2008 (the last business day of the Registrant’s most recently completed second fiscal quarter) was $4,104,429 based upon a total of 519,548 shares held as of June 30, 2008 by persons believed to be non-affiliates of the Registrant. The basis of the calculation does not constitute a determination by the Registrant as defined in Rule 405 of the Securities Act of 1933, as amended, such calculation, if made as of a date within sixty days of this filing, would yield a different value.
As of March 24, 2010, there were 1,946,935 shares of common stock outstanding.
DOCUMENTS INCORPORATED BY REFERENCE
NONE

AMENDMENT #1 FOR ANNUAL REPORT ON 10-K FOR
NEW CONCEPT ENERGY, INC.
The undersigned registrant hereby amends the following items, exhibits, or other portions of its Annual Report on Form 10-K for the fiscal year ended December 31, 2009 as set forth below in the substituted pages attached hereto which replace the same numbered pages in the original filing.

· | Page 3, Item 1 – Business – “Oil and Gas Operations” added second and third paragraphs

· | Page 8, Item 2 – “Oil and Gas” added disclosures pertaining to Reserves Estimation, Development Plan, Proved Reserves, Well Statistics and Acreage Statistics

· | Page 15, Item 7 – “Oil and Gas Property Accounting” revised Disclosure

· | Page 42, Note A – “Business Description and Presentation” - Acquisition of Carl E. Smith Companies - Added Disclosure pertaining to the purchase price paid and opening balance sheet for the acquisition of Carl E. Smith etal

· | Page 46, Note B – “Full Cost Accounting” - Summary of Significant Accounting Policies - revised disclosure for full cost accounting

· | Page 60-62, Note P – “Supplemental Financial Information on Oil and Natural Gas Exploration, Development and Production Activities (unaudited)” added tables

· | “Exhibit 23.2” - Added Consent of Independent Petroleum Consultant

· | “Exhibit 31.1” - Rule 13a-14(e) Certification by Principal Executive Officer and Chief Financial Officer

· | “Exhibit 32.1” – Certification of Principal Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. § 1350, as adopted pursuant to Section 906 of the Sarbanes Oxley Act of 2002

· | “Exhibit 99.1” - Reserve Study letter dated March 23, 2010 prepared by Lee Keeling and Associates, Inc. – added report

· | “Exhibit 99.2” – Letter from Lee Keeling and Associates, Inc. dated March 11, 2010 amending report letter of December 31, 2008

Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, the Registrant has duly caused this Amendment to be signed on its behalf by the undersigned, thereunto duly authorized.

Dated: November 17, 2010 | New Concept Energy, Inc.
| By: /s/ Gene S. Bertcher
| Gene S. Bertcher
| Principal Executive Officer,
| President and Chief Financial Officer

NEW CONCEPT ENERGY, INC.
Index to Annual Report on Form 10-K
Fiscal year ended December 31, 2009

Forward-Looking Statements | - 3 -
PART I | - 3 -
Item 1. Business | - 3 -
Item 1A. Risk Factors | - 7 -
Item 1B. Unresolved Staff Comments | - 8 -
Item 2. Properties | - 8 -
Item 3. Legal Proceedings | -11-
Item 4. Submission of Matters to a Vote of Security Holders | - 11 -
PART II | - 12 -
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities | - 12 -
Item 6. Selected Financial Data | - 13 -
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operation | - 14 -
Item 7a: Quantitative And Qualitative Disclosures About Market Risk | - 18 -
Item 8. Financial Statements and Supplementary Data | - 18 -
Item 9. Changes In and Disagreements With Accountants on Accounting and Financial Disclosure | - 18 -
Item 9A(T). Controls and Procedures | - 18 -
Item 9B. Other Information | - 19-
PART III | - 20 -
Item 10. Directors, Executive Officers and Corporate Governance | - 20 -
Item 11. Executive Compensation | - 24 -
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters | - 25 -
Item 13. Certain Relationships and Related Transactions and Director Independence | - 27 -
Item 14. Principal Accounting Fees and Services | - 28 -
PART IV | - 30 -
Item 15. Exhibits and Financial Statement Schedules | - 30 -
SIGNATURES | - 33 -
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM | - 34 -

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Forward-Looking Statements
Certain statements in this Form 10-K are forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act of 1933, and Section 21E of the Securities Exchange Act of 1934. The words “estimate”, “plan”, “intend”, “expect”, “anticipate”, “believe” and similar expressions are intended to identify forward-looking statements. These forward-looking statements are found at various places throughout this Report and in the documents incorporated herein by reference. New Concept Energy, Inc. disclaims any intention or obligation to update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. Although we believe that our expectations are based upon reasonable assumptions, we can give no assurance that our goals will be achieved. Important factors that could cause our actual results to differ from estimates or projections contained in any forward-looking statements are described under Item 1A. Risk Factors beginning on page -7-.
PART I
Item 1. Business
New Concept Energy, Inc. (“New Concept”, “NCE” or the “Company” or “we” or “us”) was incorporated in Nevada on May 31, 1991, under the name Medical Resource Companies of America, Inc. The Company is the successor-by-merger to Wespac Investors Trust, a California business trust that began operating in 1982. On March 26, 1996, the name was changed to Greenbriar Corporation. On February 8, 2005, the name of the Company was changed to CabelTel International Corporation. On May 21, 2008, the name of the company was changed to New Concept Energy, Inc.
Oil and Gas Operations
In September 2008, the Company completed the acquisition of certain entities, mineral interests and related assets through its wholly owned subsidiaries Mountaineer State Energy, Inc. and Mountaineer State Operations, LLC. The Company now operates oil and gas wells and mineral leases in Athens and Meigs Counties in Ohio and in Calhoun, Jackson and Roane Counties in West Virginia. The assets acquired included 114 producing gas wells, 101 non-producing wells and related equipment and mineral leases.
At December 31, 2009, 122 wells are producing. The Company engaged the firm of independent oil and gas engineers Lee Keeling & Associates, Inc. to estimate the net oil and gas reserves. On the basis of their study, the estimate of the present value of future net revenues were estimated to be $11.4 million at December 31, 2009.
The wells in West Virginia and Ohio were drilled prior to acquisition. The majority of wells are located on leased property under mineral rights contracts. While some wells were drilled in the 1960’s, the majority were drilled in the 1970’s and 1980’s. The acquisition was contemplated with the intention of re-working existing wells in different geological formations using modern technologies, and then drilling new wells in strategic locations.
In addition to the wells and mineral leases, the acquisition included a complex covering approximately 41 acres of land with 8,000 square feet of office and storage buildings, an adjacent 12 acre site with a 24 stall horse barn, machinery and equipment in excess of the needs of the gas operation and approximately $1.5 million in cash. During 2009, the Company sold various equipment and vehicles not necessary for operations. As of December 31, 2009, the horse barn, the undeveloped land, and one piece of heavy equipment remain unsold.
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Estimates of total, proved net oil or gas reserves
Reserve Rule Changes: During 2009, the SEC issued its final rule on the modernization of oil and gas reporting (the "Reserve Ruling") and the Financial Accounting Standards Board (the "FASB") issued Accounting Standards Update No. 2010-03 ("ASU 2010-03") "Extractive Industries – Oil and Gas," which aligns the estimation and disclosure requirements of FASB Accounting Standards Codification Topic 932 with the Reserve Ruling. The Reserve Ruling and ASU 2010-03 are effective for Annual Reports on Form 10-K for fiscal years ending on or after December 31, 2009. The key provisions of the Reserve Ruling and ASU 2010-03 are as follows:

· | Expanding the definition of oil and gas-producing activities to include the extraction of saleable hydrocarbons, in the solid, liquid or gaseous state, from oil sands, coalbeds or other nonrenewable natural resources that are intended to be upgraded into synthetic oil or gas, and activities undertaken with a view to such extraction;

· | Amending the definition of proved oil and gas reserves to require the use of an average of the first-day-of-the-month commodity prices during the 12-month period ending on the balance sheet date rather than the period-end commodity prices;

· | Adding to and amending other definitions used in estimating proved oil and gas reserves, such as "reliable technology" and "reasonable certainty";

· | Broadening the types of technology that an issuer may use to establish reserves estimates and categories; and,

· | Changing disclosure requirements and providing formats for tabular reserve disclosures.

According to our independent reserve engineering firm, Lee Keeling & Associates, Inc., as of December 31, 2009, our Proved Reserves were approximately 7.6 million Mcf of natural gas. Of the total Proved Reserves, approximately 38% were Proved Developed Reserves. As of December 31, 2009, the related PV-10 of our Proved Reserves was approximately $11.4 million. During the year ended December 31, 2009, we produced approximately 236,000 Mcf of natural gas.
Additional Oil and Gas Information

· | Average sales price per unit - $5.26 per Mcf

· | Average production cost per unit – $3.05 per Mcf

· | Productive wells – 122 productive wells

· | Developed acreage – approximately 20,000 acres

· | Drilling activity – Since the date of acquisition, the Company has reworked numerous wells and is continuing the reworking of additional wells in 2010. In 2010, we have tentatively scheduled a “behind-the-pipe” drilling schedule, in addition to new site drilling, subject to favorable market conditions.

· | Delivery Commitments – For fiscal 2010, the Company has contracted with Dominion Field Services, Inc. to purchase the Company’s gas production. The contract is separated into production from the Ohio wells and the West Virginia wells. Ohio gas is under contract for $6.01 per dekatherm and West Virginia gas at $6.08 per dekatherm at a volume of 20,000 dekatherms per month. Our gas converts from dekatherms to Mcf at a ratio of approximately 1.2, which equates to 16,667 Mcf per month. There is no penalty to the Company for not reaching the contract volume. Volume exceeding the contract volume will be settled at the spot price.

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Retirement Community
The Company leases and operates Pacific Pointe Retirement Inn (“Pacific Pointe”) in King City, Oregon. Pacific Pointe began operations in 1993, has a capacity of 114 residents and provides community living with basic services such as meals, housekeeping, laundry, 24/7 staffing, transportation and social and recreational activities. These residents do not yet need assistance or support with activities of daily living but prefer the physical and psychological comfort of a residential community of like-minded people and access to senior-oriented services.
At Pacific Pointe, the Company’s marketing and sales efforts are undertaken at the local level. These efforts are intended to create awareness of our community and its services among prospective residents, their families, other key decision-makers and professional referral sources.
Business Strategy
The Company is a Nevada corporation which had historically been a real estate company, owning or leasing retirement specific real estate, an outlet shopping mall (sold 2008) and certain oil and natural gas leases through subsidiaries.
The Company intends to continue to pursue acquisition of undervalued or distressed oil and gas related businesses, as well as additional acquisitions of oil and gas leases. The Company may choose to develop or resell the acquired acreage as management deems most beneficial to the Company.
The Company intends to maintain its interest in the retirement center, however, for the foreseeable future, management intends to focus its efforts on oil and gas and energy related investments.
Insurance
The Company currently maintains property and liability insurance intended to cover claims in its oil and gas operations, retirement community and corporate operations. The provision of personal services entails an inherent risk of liability compared to more institutional long-term care communities. The Company also carries property insurance on each of its owned and leased properties, as appropriate.
Employees
At December 31, 2009, the Company employed, in all segments, 51 people (26 full-time and 25 part-time). The Company believes it maintains good relationships with its employees. None of the Company’s employees are represented by a collective bargaining group.
The Company’s operations are subject to the Fair Labor Standards Act. Many of the Company’s employees are paid at rates related to the minimum wage and any increase in the minimum wage will result in an increase in labor costs.
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Management is not aware of any non-compliance by the Company as regards applicable regulatory requirements that would have a material adverse effect on the Company’s financial condition or results of operations.
Quality Assurance
Energy Philosophy – The Company is committed to the preservation and enhancement of the environment in which we operate. We are philosophically and operationally focused to continually prioritize the sensitivity of our ecological system in which we develop resources for our generation as well as our children’s. Management’s legacy is to prove that the energy industry can develop the earth’s natural resources with clean and efficient technologies while preserving its fragile beauty. Our technologies directly and significantly reduce the impact of our operations on nature and wildlife by minimizing surface disturbance.
Retirement Center Philosophy – The Company’s philosophy of management is to demonstrate by its actions and require from its employees high standards of personal integrity, to develop a climate of openness and trust, to demonstrate respect for human dignity in every circumstance, to be supportive in all relationships, to promote teamwork by involving employees in the management of their own work and to promote the free expression of ideas and opinions. In operating a retirement community, our commitment to quality assurance is designed to achieve a high degree of resident and family member satisfaction with the care and services the Company provides.
Regular Property Inspections – Property inspections are conducted by corporate personnel. These inspections cover the appearance of the exterior and grounds, the appearance and cleanliness of the interior, the professionalism and friendliness of staff and notes on maintenance.
Marketing
One purchaser comprises approximately 90% of the Company’s natural gas production. While there is an available market for crude oil and natural gas production, we cannot be assured that the loss of this purchaser would not have a material impact on the Company.
At Pacific Pointe, the Company’s marketing and sales efforts are undertaken at the local level. These are intended to create awareness of our property and its services among prospective residents, their families and other key referral sources. The property engages in traditional types of marketing activities such as special events, radio spots, direct mailings, print advertising, signs and yellow page advertising. These marketing activities and media advertisements are directed to potential customers.
Government Regulation
Management is not aware of any non-compliance by the Company as regards applicable regulatory requirements that would have a material adverse effect on the Company’s financial condition or results of operations.
Competition
The oil and natural gas industry is highly competitive. We encounter strong competition from other independent operators and from major oil companies in acquiring properties, contracting for drilling equipment and securing trained personnel. Many of these competitors have financial and technical resources and personnel substantially larger than ours. As a result, our competitors may be able to pay more for desirable leases, or to evaluate, bid for and purchase a greater number of properties or prospects than our financial or personnel resources will permit.
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We are also affected by competition for drilling rigs and the availability of related equipment. In the past, the oil and natural gas industry has experienced shortages of drilling rigs, equipment, pipe and personnel, which has delayed development drilling and other exploitation activities and has caused significant price increases. We are unable to predict when, or if, such shortages may again occur or how they would affect our development and exploitation program.
Competition is also strong for attractive oil and natural gas producing properties, undeveloped leases and drilling rights, and we cannot assure you that we will be able to compete satisfactorily. Many large oil companies have been actively marketing some of their existing producing properties for sale to independent producers. We regularly evaluate acquisition opportunities and submit bids as part of our growth strategy.
Our retirement community is in a highly competitive environment which and will continue to become increasingly competitive in the future. The Company competes with other retirement companies and numerous other companies providing similar long-term care alternatives, such as home healthcare agencies, community-based service programs and convalescent centers (nursing homes).
Available Information
The Company maintains an internet website at www.newconceptenergy.com. The Company has available through the website, free of charge, Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, reports filed pursuant to Section 16 of the Securities Exchange Act of 1934 (the “Exchange Act”) and amendments to those reports as soon as reasonably practicable after we electronically file or furnish such materials to the Securities and Exchange Commission. In addition, the Company has posted the charters for our Audit Committee, Compensation Committee and Governance and Nominating Committee, as well as our Code of Business Conduct and Ethics, Corporate Governance Guidelines on Director Independence and other information on the website. These charters and principles are not incorporated in this Report by reference. The Company will also provide a copy of these documents free of charge to stockholders upon request. The Company issues Annual Reports containing audited financial statements to its common stockholders.
Item 1A. Risk Factors
Risks Related to the Company
An investment in our securities involves various risks. An investor should carefully consider the following risk factors in conjunction with the other information in this report before trading our securities.
The oil & gas industry is highly competitive. Competition for leasehold interests, subcontractors and qualified employees are keen and we are competing against companies that are larger, more experienced and better capitalized than we are.
Our governing documents contain anti-takeover provisions that may make it more difficult for a third party to acquire control of us. Our Articles of Incorporation contain provisions designed to discourage attempts to acquire control of the Company by a merger, tender offer, proxy contest or removal of incumbent management without the approval of our Board of Directors. As a result, a transaction which otherwise might appear to be in your best interests as a stockholder could be delayed, deferred or prevented altogether, and you may be deprived of an opportunity to receive a premium for your shares over prevailing market rates. The provisions contained in our Articles of Incorporation include:
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| ● | the requirement of an 80% vote to make, adopt, alter, amend, change or repeal our Bylaws or certain key provisions of the Articles of Incorporation that embody, among other things, the anti-takeover provisions;

| ● | the so-called business combination “control act” requirements involving the Company and a person that beneficially owns 10% or more of the outstanding common stock except under certain circumstances; and

| ● | the requirement of holders of at least 80% of the outstanding Common Stock to join together to request a special meeting of stockholders.

As of March 27, 2010, a group of entities owned and controlled approximately 69% of the Company’s outstanding common stock. This group has the power to block any attempted change in control – See Item 12 – Security Ownership of Certain Beneficial Owners and Management and Related Shareholder Matters.
Item 1B. Unresolved Staff Comments
Not applicable.
Item 2. Properties
The Company’s principal offices are located at 1755 Wittington Place, Dallas, Texas 75234 in approximately 5,000 square feet of leased office space. The Company believes this space is presently suitable, fully utilized and will be adequate for the foreseeable future.
Retirement Community
The Company leases and operates Pacific Pointe Retirement Inn (“Pacific Pointe”) in King City, Oregon. Pacific Pointe began operations in 1993, has a capacity of 114 residents and provides community living with basic services such as meals, housekeeping, laundry, 24/7 staffing, transportation and social and recreational activities. These residents do not yet need assistance or support with activities of daily living but prefer the physical and psychological comfort of a residential community of like-minded people and access to senior-oriented services.
The Company’s retirement community is suitable and adequate for the purpose to which it is devoted.
Oil and Gas
Reserve Estimation
The Company’s producing properties have been in production for over 20 years. Because individual well production volumes were not available, composite production decline curves were constructed for each of the five counties in which these wells are located. All five composite decline curves exhibit well-established production decline trends. After reviewing all available information, it was determined that the most reliable method of estimating the Proved Developed Producing Reserves was by extrapolation of the existing production decline trends to the economic limit of production.
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Proved Undeveloped Reserves were estimated by analogy to currently producing wells in the various areas producing from the same formations.
The Company’s reserve reports are prepared by independent petroleum engineers. The process used to control the information provided to the independent petroleum engineers includes an initial compilation of production data by experienced senior management personal in the Company’s field office. This data is independently reviewed by appropriate personal in the Company’s corporate office prior to being submitted to the independent petroleum engineer. The submitted data is ultimately compared to the final reserve report and then agreed to the financial statement disclosures prepared by the Company.
The Company uses the petroleum engineering firm of Lee Keeling and Associates, Inc. to prepare its reserve estimates and future net revenues from its oil and gas properties. The work is performed by a registered professional engineer who is a member of the Society of Petroleum Engineers with over 40 years of experience in the oil and gas industry.
Development plan
In September 2008, the Company through its acquisition of Carl E. Smith, Inc. acquired 20,000 acres of mineral rights in Ohio and West Virginia. The 20,000 acres are both surrounded and interspersed of hundreds of existing wells of which 114 producing wells were owned by Carl E. Smith, Inc. and other non-related owners owed the rest of such wells. The entire area has pipelines in place and decades of information regarding reserves.
In connection with the acquisition, the Company formulated a development plan to rework existing wells, to improve production using modern technology (both in proved developed and proved undeveloped reserves), and to drill new wells (in proved undeveloped reserves). The Company’s independent petroleum engineer prepared reserve studies as of the acquisition date, December 31, 2008 and 2009 based upon existing production from the Company’s and other wells in the area and the Company’s plan for drilling in the undeveloped reserves portion of the acreage. The Company’s plan is to use the current knowledge of the area and new technologies available to both rework its existing wells and drill new wells. The new wells will be drilled in areas currently designated as proved undeveloped. The Company intended to begin implementing its drilling program immediately.
During the year ending December 31, 2009, the Company increased the number of operating wells from 114 to 122, but due to the economy, was behind on its original time table for drilling new wells. In early 2010, the Company revised its development plan and committed additional resources to drilling new wells.
Proved Reserves
The following table presents our estimated proved reserves as of December 31, 2009. These estimates correspond with the method used in presenting the “Supplemental Information on Oil and Gas Operations” in Note P to our consolidated financial statements included in this report.
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|  | Gas |  |  | Oil |
|  | (MBBLS) |  |  | (MMCF) |
Proved Reserves |  |  |  |  |  |
U.S. Onshore |  |  |  |  |  |
Developed Producing |  |  | 2,467 |  |  |  | 19 |
Developed Non-Producing |  |  | 400 |  |  |  | - |
Undeveloped |  |  | 4,694 |  |  |  | - |
Total Proved Reserves |  |  | 7,561 |  |  |  | 19 |

The following table presents the changes in our total proved undeveloped reserves.

|  | Gas |  |  | Oil |
|  | (MBBLS) |  |  | (MMCF) |
Proved undeveloped reserves as of December 31, 2007 |  |  | - |  |  |  | - |
Purchases of reserves in place |  |  | 4,694 |  |  |  | - |
Conversion to proved developed reserves |  |  | - |  |  |  | - |
Proved undeveloped reserves as of December 31, 2008 |  |  | 4,694 |  |  |  | - |
Conversion to proved developed reserves |  |  | - |  |  |  | - |
Proved undeveloped reserves as of December 31, 2009 |  |  | 4,694 |  |  |  | - |

Well Statistics
The following table sets forth our wells (all natural gas) as of December 31, 2009.

|  | Acres |
|  | Gross (1) |  |  | Net (2) |
U.S. Onshore |  |  |  |  |  |
Producing |  |  | 122 |  |  |  | 122 |
Non-Producing |  |  | 93 |  |  |  | 93 |
Total wells |  |  | 215 |  |  |  | 215 |

(1) Gross wells are the sum of all wells in which we own an interest.
(2) Net wells are gross wells multiplied by our fractional working interests on the well.
Acreage Statistics
The following table sets forth our developed and undeveloped oil and gas lease and mineral acreage as of December 31, 2009.

|  | Acres |
|  | Gross (1) |  |  | Net (2) |
U. S Onshore |  |  |  |  |  |
Developed |  |  | 19,375 |  |  |  | 19,375 |
Undeveloped |  |  | - |  |  |  | - |
Total Acreage |  |  | 19,375 |  |  |  | 19,375 |

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(1) Gross acres are the sum of all acres in which we own an interest.
(2) Net acres are gross acres multiplied by our fractional working interests on the acreage.
Item 3. Legal Proceedings
Chesapeake Exploration Limited Partnership and Chesapeake Operating, Inc. (“Chesapeake”)
In January 2006, the Company entered into a joint operating agreement evidencing its acquisition of a 5% interest in two gas wells being drilled and ultimately operated by Chesapeake. The Company relied on the cost projections provided by Chesapeake to make its investment decision. Subsequent to its investment, the Company received an invoice from Chesapeake for $556,217 which, according to Chesapeake, represents the Company’s 5% share of additional costs incurred by Chesapeake in drilling the wells. The Company believes that these additional costs far exceed any reasonable expense that should have been incurred in drilling the two wells and were incurred without notifying the Company of such expenses. The Company has requested an accounting of the additional expenses and a reconciliation of the final costs to the cost estimates previously presented. In April 2007, Chesapeake filed a lawsuit against the Company and others in District Court of Tarrant County, Texas.
Item 4. Submission of Matters to a Vote of Security Holders
An Annual Meeting of Stockholders was held on December 17, 2009, at which meeting stockholders were asked to consider and vote upon the election of directors. At the meeting, stockholders elected the following individuals as directors:

| Shares Voting |
Director | FOR | AGAINST | ABSTAINED
Roz Campisi Beadle | 1,493,342 | 102 | 49,960
Gene S. Bertcher | 1,493,340 | 104 | 49,960
James E. Huffstickler | 1,493,342 | 102 | 49,960
Dan Locklear | 1,493,342 | 102 | 49,960
Victor L. Lund | 1,493,402 | 42 | 49,960

There were no broker non-votes in the election of directors at the annual meeting.
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PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities
Market Information
The common stock of the Company is listed and traded on the American Stock Exchange (“AMEX”) using the symbol “GBR”. The following table sets forth the high and low sales prices as reported in the reporting system of the AMEX and other published financial sources

| 2009 |  | 2008
| High | Low |  | High | Low
First Quarter | 4.50 | 2.78 |  | 2.87 |  | 1.15
Second Quarter | 5.40 | 3.01 |  | 14.16 |  | 2.20
Third Quarter | 7.50 | 5.15 |  | 10.15 |  | 4.75
Fourth Quarter | 6.79 | 4.01 |  | 7.82 |  | 3.24

On March 24, 2010 the closing price of the Company’s common stock was $4.49 per share. According to the Transfer Agent’s records, at March 24, 2010 our common stock was held by approximately 436 holders of record.
Dividends
The Company paid no dividends on its common stock in 2009 or 2008. The Company has not paid cash dividends on its common stock during at least the last ten fiscal years and it has been the policy of the Board of Directors of the Company to retain all earnings to pay down long-term debt and finance future expansion and development of its businesses. The payment of dividends, if any, will be determined by the Board of Directors in the future in light of conditions then existing, including the Company’s financial condition and requirements, future prospects, restrictions in financing agreements, business conditions and other factors deemed relevant by the Board of Directors.
Securities Authorized for Issuance under Equity Compensation Plans
A stock-based equity compensation plan has been approved by our stockholders. See Note I - Stockholders Equity for a description of the plan, the number of shares of common stock to be issued upon exercise of outstanding stock options, the weighted average exercise price of outstanding stock options and the number of shares of common stock remaining for future issuance under the plans. We have no stock-based compensation plans which were adopted without the approval of our stockholders. The plan expired on June 2, 2009.
Purchases of Equity Securities
The Board of Directors has not authorized the repurchase of any shares of its common stock under any share repurchase program, except when stockholders owning less than one round lot (100 shares) so request, the Company will purchase shares at market closing on the last trading day prior to receipt of the certificate(s). The Company repurchased no shares during the three months ended December 31, 2009.
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Item 6. Selected Financial Data
The selected consolidated financial data presented below are derived from the Company’s audited financial statements.

|  | December 31, |
|  | 2009 |  |  | 2008 |  |  | 2007 |
|  | (amounts in thousands, except per share amounts) |
Operating revenue |  | $ | 4,098 |  |  | $ | 3,560 |  |  | $ | 2,984 |
Operating expenses |  |  | 6,827 |  |  |  | 3,702 |  |  |  | 2,956 |
Operating profit (loss) |  |  | (2,729 | ) |  |  | (142 | ) |  |  | 28 |
Earnings (loss) from continuing operations before income taxes |  |  | (2,210 | ) |  |  | 17,269 |  |  |  | 959 |
Income tax (expense) |  |  | — |  |  |  | (1,774 | ) |  |  | (270 | )
Earnings (loss) from continuing operations |  |  | (2,210 | ) |  |  | 15,495 |  |  |  | 689 |
Income (loss) from discontinuedoperations |  |  | — |  |  |  | — |  |  |  | (627 | )
NET EARNINGS (LOSS) |  | $ | (2,210 | ) |  | $ | 15,495 |  |  | $ | 62 |
Earnings (loss) per common share – basic and diluted |  |  |  |  |  |  |  |  |  |  |  |
Continuing operations |  | $ | (1.27 | ) |  | $ | 8.92 |  |  | $ | 0.70 |
Discontinued operations |  |  | — |  |  |  | — |  |  |  | (0.64 | )
Net earnings per share |  | $ | (1.27 | ) |  | $ | 8.92 |  |  | $ | 0.06 |
Basic weighted average common shares |  |  | 1,737 |  |  |  | 1,737 |  |  |  | 987 |
Balance Sheet Data: |  |  |  |  |  |  |  |  |  |  |  |
Total assets |  | $ | 25,121 |  |  | $ | 26,392 |  |  | $ | 9,786 |
Long-term debt |  |  | 1,524 |  |  |  | 1,430 |  |  |  | 6,921 |
Asset retirement obligation |  |  | 2,450 |  |  |  | 2,334 |  |  |  | — |
Total liabilities |  |  | 6,839 |  |  |  | 3,566 |  |  |  | 7,645 |
Total stockholders equity |  | $ | 18,282 |  |  | $ | 20,492 |  |  | $ | 2,141 |

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operation
Overview
Effective September 1, 2008, the Company completed the acquisition of certain entities, mineral interests and related assets through entities named Carl E. Smith, Inc., a West Virginia corporation, two of its affiliates, Carl E. Smith Petroleum, Inc. and Carl E. Smith Real Estate, Inc. and other privately owned related assets (collectively “CESI”). Immediately after the acquisition, all of the acquired entities and assets were merged into Carl E. Smith, Inc., the name of which was changed to Mountaineer State Energy, Inc. (“Mountaineer”) which became a wholly-owned subsidiary of NCE. The assets acquired include 94 producing gas wells, 121 non-producing wells and related equipment, mineral leases covering 20,000 acres located in Athens and Meigs Counties in Ohio as well as Calhoun, Jackson and Roane Counties in West Virginia. In addition to the wells and mineral leases, the acquisition included a complex covering approximately 41 acres of land with 8,000 square feet of office and storage buildings, an adjacent 12 acre site with a 24 stall horse barn, machinery and equipment in excess of the needs of the gas operation and approximately $1.5 million in cash. NCE has evaluated the excess equipment and since the acquisition has sold currently plans on selling certain excess land and equipment not needed for current or planned future operations.
The cash portion of the asset acquisition totaling approximately $13.9 million was paid from existing working capital held by NCE.
As part of the acquisition the Company entered into certain non interest bearing long term obligations which will paid out over the next 16 years. The Company has evaluated the above notes and after factoring in certain offsets provided for in the agreement has valued the above obligations at $1,198,000 at December 31, 2009.
As of December 31, 2009, the Company leased one independent living community in Oregon, with a capacity of 114 residents.
A number of years ago the Company has owned, leased and operated assisted living and retirement communities throughout the United States. During that period of time the Company has both acquired and sold over seventy communities. The property in Oregon is a holdover from that time period. While not an integral part of our business plan the one remaining facility is profitable and it is anticipated that it will remain a part of the Company’s operations.
In 2007, the Company acquired interests in a significant block of oil and natural gas leases in Cleburne County, Arkansas covering approximately 1,712 net acres. The Company originally intended to drill on the acreage however an opportunity arose to sell the acreage and in 2008 we sold those mineral rights for a gain of approximately $16.4 million.
Critical Accounting Policies and Estimates
The Company’s discussion and analysis of its financial condition and results of operations are based upon the Company’s consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States. Certain of the Company’s accounting policies require the application of judgment in selecting the appropriate assumptions for calculating financial estimates. By their nature, these judgments are subject to an inherent degree of uncertainty. These judgments and estimates are based upon the Company’s historical experience, current trends and information available from other sources that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying value of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates under different assumptions or conditions.
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The Company believes the following critical accounting policies are more significant to the judgments and estimates used in the preparation of its consolidated financial statements. Revisions in such estimates are recorded in the period in which the facts that give rise to the revisions become known.
Oil and Gas Property Accounting
The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under this method of accounting, all costs of acquisition, exploration and development of oil and natural gas properties (including such costs as leasehold acquisition costs, geological expenditures, dry hole costs, tangible and intangible development costs and direct internal costs) are capitalized as the cost of oil and natural gas properties when incurred.
The full cost method requires the Company to calculate quarterly, by cost center, a “ceiling,” or limitation on the amount of properties that can be capitalized on the balance sheet. To the extent capitalized costs of oil and natural gas properties, less accumulated depletion and related deferred taxes exceed the sum of the discounted future net revenues of proved oil and natural gas reserves, the lower of cost or estimated fair value of unproved properties subject to amortization, the cost of properties not being amortized, and the related tax amounts, such excess capitalized costs are charged to expense. Beginning December 31, 2009, full cost companies use the unweighted arithmetic average first day of the month price for oil and natural gas for the 12-month period preceding the calculation date to calculate the future net revenues of proved reserves. Prior to December 31, 2009, companies used the price in effect at the calculation date and had the option, under certain circumstances, to elect to use subsequent commodity prices if they increased after the calculation date.
At December 31, 2009, the Company’s net book value of oil and natural gas properties exceeded the ceiling amount based on the unweighted arithmetic average of the first day of each month for the 12-month period ended December 31, 2009. As a result, the Company recorded a full cost ceiling adjustment before income taxes of approximately $1.7 million.
The Company assesses any unproved oil and gas properties on an annual basis for possible impairment or reduction in value. The Company assesses properties on an individual basis or as a group if properties are individually insignificant. The assessment includes consideration of the following factors, among others: intent to drill; remaining lease term; geological and geophysical evaluations; drilling results and activity; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment of unproved properties not subject to amortization, the associated costs incurred to date for such properties are then included in unproved properties subject to amortization.
Oil and Gas Reserves
Our proved oil and gas reserves are estimated by independent petroleum engineers. Reserve engineering is a subjective process that is dependent upon the quality of available data and the interpretation thereof, including evaluations and extrapolations of well flow rates and reservoir pressure. Estimates by different engineers often vary, sometimes significantly. In addition, physical factors such as the results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors such as changes in product prices, may justify revision of such estimates. Because proved reserves are required to be estimated using prices at the date of the evaluation, estimated reserve quantities can be significantly impacted by changes in product prices.
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Depreciation, depletion and amortization (“DD&A”) of producing properties is computed on the unit-of-production method based on estimated proved oil and gas reserves. While total DD&A expense for the life of a property is limited to the property’s total cost, proved reserve revisions result in a change in timing of when DD&A expense is recognized. Downward revisions of proved reserves result in an acceleration of DD&A expense, while upward revisions tend to lower the rate of DD&A expense recognition.
The standardized measure of discounted future net cash flows and changes in such cash flows are prepared using assumptions required by the Financial Accounting Standards Board and the Securities and Exchange Commission. Such assumptions include using year-end oil and gas prices and year-end costs for estimated future development and production expenditures. Discounted future net cash flows are calculated using a 10% rate. Changes in any of these assumptions could have a significant impact on the standardized measure. Accordingly, the standardized measure does not represent management’s estimated current market value of proved reserves.
The Company’s allowance for doubtful accounts receivable and notes receivable is based on an analysis of the risk of loss on specific accounts. The analysis places particular emphasis on past due accounts. Management considers such information as the nature and age of the receivable, the payment history of the tenant, customer or other debtor and the financial condition of the tenant or other debtor. Management’s estimate of the required allowance, which is reviewed on a quarterly basis, is subject to revision as these factors change.
Deferred Tax Assets
Significant management judgment is required in determining the provision for income taxes, deferred tax assets and liabilities and any valuation allowance recorded against net deferred tax assets. The future recoverability of the Company’s net deferred tax assets is dependent upon the generation of future taxable income prior to the expiration of the loss carry forwards. At December 31, 2009, the Company had a deferred tax asset due to tax deductions available to it in future years. However, as management could not determine that it was more likely than not that the benefit of the deferred tax asset would be realized, a 100% valuation allowance was established.
Liquidity and Capital Resources
At December 31, 2009, the Company had current assets of $12.1 million and current liabilities of $2.9 million.
Cash and cash equivalents totaled $155,000 at December 31, 2009 and $190,000 at December 31, 2008. New Concept’s principal sources of cash are property operations, sales of oil and gas, and proceeds from sales of assets. At December 31, 2009 the Company had $11.2 million invested in short term notes receivable with interest at the prime rate plus two percent.
Net cash provided by (used in) continuing operating activities was $736,000 in 2009, $427,000 in 2008, and $749,000 in 2007.
Net cash provided by (used in) investing activities was $(823,000) in 2009, $2.6 million in 2008, $(679,000) in 2007.
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Net cash provided by (used in) financing activities was $52,000 in 2009, $(3.0 million) in 2008, and $-0- in 2007. The $3.0 million used in 2008 was the result of the payment of related party debt of $6.9 million, partially offset by receipt of $2.9 million for the issuance of 950,000 shares of common stock.
There were no discontinued operations in 2009 or 2008. Net cash provided (used in) discontinued operations was ($222,000) in 2007.
Results of Operations
Fiscal 2009 as compared to 2008
Revenues and Operating Expenses: Total revenues for 2009 totaled $4.1 million compared to $3.6 million in 2008. The primary reason for the increase is the acquisition of the oil and gas operations in September 2008. Fiscal 2009 reflects a full twelve months of operating revenue for the oil and gas operations, while 2008 reflects only four months of such revenue. Oil and gas revenue did not increase as much as may have been anticipated due to the expiration of a fixed-price contract in the first quarter of 2009. For the remainder of the year, gas was sold at the spot price, which was substantially less than the original contract price.
Revenue for the retirement facility totaled approximately $2.9 million for 2008 and 2009.
Operating expenses totaled $6.8 million for 2009 compared to $3.7 million for 2008. In 2009, oil and gas operating costs totaled $1.5 million compared to $496,000 in 2008 due to the acquisition of the oil and gas operations described above. In 2009, the Company recorded a non-cash charge to operations of $1.7 million for impairment of natural gas and oil properties, pursuant to the results of the full-cost ceiling test. Also in 2009, the Company recorded accretion of discount related to its asset retirement obligation of $116,000. Real estate operating expenses remained relatively constant. Corporate general and administrative expenses increased from $852,000 to $1.2 million, due primarily to the write-down of receivables of approximately $200,000 and the accrual of $200,000 in interest and penalties on unpaid taxes, offset by reductions in salaries and wages of approximately $50,000.
Interest Income: Interest income decreased approximately $200,000 from 2008 to 2009 due to the reduction interest rate on portions of the notes receivable from eight percent to the prime rate plus two percent during 2009.
Interest Expense: Interest expense for 2009 decreased approximately $150,000 due to the pay-off of $6.9 million of related party debt in the first quarter of 2008.
Gain on sale of assets: In 2008, the Company sold its investment in mineral rights in the Fayetteville Shale for a gain of approximately $16.4 million. No gain or loss was recorded on sales of assets in 2009.
Other Income: Other income decreased from $464,000 in 2008 to $68,000 in 2009. Other income in 2008 is primarily due to cash received from receivables that were previously fully reserved.
Fiscal 2008 as Compared to 2007
Revenues and Operating Expenses: Revenues for 2008 totaled $3.6 million compared to $3.0 million in 2007. The primary reason for the increase is the acquisition of the oil and gas operations in West Virginia and Ohio in September, 2008, which provided $672,000 of net revenue. Revenue for the retirement facility totaled approximately $2.9 million in 2008 as compared to $3.0 million for 2007.
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Operating expenses totaled $3.7 million for 2008 compared to $3.0 million for 2007. In 2008, oil and gas operating costs totaled $496,000, and corporate general and administrative expenses increased approximately $60,000, primarily due to the administrative costs of the acquisition.
Interest Income: Interest income increased approximately $670,000 from 2007 to 2008 due to the increase in the interest-bearing loans to affiliates during 2008.
Interest Expense: Interest expense for 2008 increased approximately $197,000 due primarily to the amount of time debt was owed. Interest on the note payable to affiliate in 2007 reflects less than two months of accrued interest, while 2008 interest is for more than four months.
Gain on sale of assets: In 2008, the Company sold its investment in mineral rights in the Fayetteville Shale for a gain of approximately $16.4 million. In 2007, the Company sold a participation in the future cash flow of its retirement community in King City, Oregon and recorded a gain of $750,000.
Other Income: Other income increased from $143,000 in 2007 to $464,000 in 2008. The increase in 2008 is primarily due to cash received from receivables that were previously fully reserved.
Item 7a: Quantitative And Qualitative Disclosures About Market Risk
All of the Company’s debt is financed at fixed rates of interest. Therefore, the Company has minimal risk from exposure to changes in interest rates.
Item 8. Financial Statements
The financial statements required by this Item begin at page 32 of this Report.
Item 9. Changes In and Disagreements With Accountants on Accounting and Financial Disclosure
None.
Item 9A. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
Based on an evaluation by our management (with the participation of our Principal Executive Officer and Principal Financial Officer), as of the end of the period covered by this report, our Principal Executive Officer and Principal Financial Officer concluded that our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended (the “Exchange Act”)) were effective to provide reasonable assurance that information required to be disclosed by us in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms and that such information is accumulated and communicated to our management, including our Principal Executive Officer and Principal Financial Officer, to allow timely decisions regarding required disclosures.
There has been no change in our internal control over financial reporting (as defined in Exchange Act Rule 13a-15(f)) during the most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
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Management’s Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting for the Company. Our internal control over financial reporting is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with generally accepted accounting principles. There are inherent limitations to the effectiveness of any system of internal control over financial reporting. These limitations include the possibility of human error, the circumvention of overriding of the system and reasonable resource constraints. Because of its inherent limitations, our internal control over financial reporting may not prevent or detect misstatements. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions or that the degree of compliance with policies or procedures may deteriorate.
Management assessed the effectiveness of the Company’s internal control over financial reporting as of December 31, 2009. In making this assessment, management used the criteria set forth in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on management’s assessments and those criteria, management has concluded that Company’s internal control over financial reporting was effective as of December 31, 2009.
This annual report does not include an attestation report of the Company’s registered public accounting firm regarding internal control over financial report. Management’s report was not subject to attestation by the Company’s registered public accounting firm pursuant to temporary rules of the Securities and Exchange Commission that permit the Company to provide only management’s report in this annual report.
Changes in Internal Control over Financial Reporting
In preparation for management’s report on internal control over financial reporting, we documented and tested the design and operating effectiveness of our internal control over financial reporting. There were no changes in our internal controls over financial reporting (as such term is defined in Exchange Act Rule 13a-15(f)) that occurred during the quarter ended December 31, 2009 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
Item 9B. Other Information
Not applicable.
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PART III
Item 10. Directors, Executive Officers and Corporate Governance
Directors
The affairs of the Company are managed by the Board of Directors. The directors are elected at the Annual Meeting of Stockholders or appointed by the incumbent Board and serve until the next Annual Meeting of Stockholders, until a successor has been elected or approved, or until earlier resignation, removal or death.
It is the Board’s objective that a majority of the Board consists of independent directors. For a director to be considered “independent”, the Board must determine that the director does not have any direct or indirect material relationship with the Company. The Board has established guidelines to assist it in determining director independence, which conform to, or are more exacting than, the independence requirements in the American Stock Exchange listing rules. The independence guidelines are set forth in the Company’s “Corporate Governance Guidelines”. The text of this document has been posted on the Company’s internet website at http://www.newconceptenergy.com, and is available in print to any stockholder who requests it. In addition to applying these guidelines, the Board will consider all relevant facts and circumstances in making an independent determination.
The Company has adopted a code of conduct that applies to all directors, officers and employees, including our principal executive officer, principal financial officer and principal accounting officer. Stockholders may find our Code of Conduct on our internet website address at http://www.newconceptenergy.com. We will post any amendments to the Code of Conduct as well as any waivers that are required to be disclosed by the rules of the SEC or the AMEX on our website.
Our Board of Directors has adopted charters for our Audit, Compensation and Governance and Nominating Committees of the Board of Directors. Stockholders may find these documents on our website by going to the website address http://www.newconceptenergy.com. Stockholders may also obtain a printed copy of the materials referred to by contacting us at the following address:
New Concept Energy, Inc.
Attn: Investor Relations
1800 Valley View Lane, Suite 300
Dallas, Texas 75234
972-407-8400 (Telephone)
The Audit Committee of the Board of Directors is an “audit committee” for the purposes of Section 3(a) (58) of the Exchange Act. The members of that Committee are Dan Locklear (Chairman), James Huffstickler and Victor L. Lund. Mr. Locklear is qualified as an “audit committee financial expert” within the meaning of SEC regulations and the Board has determined that he has the accounting and related financial management expertise within the meaning of the listing standards of the AMEX. All of the members of the Audit Committee meet the independence and experience requirements of the listing standards of the AMEX.
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All members of the Audit Committee, Compensation Committee and the Governance and Nominating Committee must be independent directors. Members of the Audit Committee must also satisfy additional independence requirements which provide (i) that they may not accept, directly or indirectly, any consulting, advisory or compensatory fee from the Company or any of its subsidiaries other than their director’s compensation (other than in their capacity as a member of the Audit Committee, the Board of Directors or any other Committee of the Board), and (ii) no member of the Audit Committee may be an “affiliated person” of the Company or any of its subsidiaries, as defined by the Securities and Exchange Commission.
The current directors of the Company are listed below, together with their ages, terms of service, all positions and offices with the Company, their principal occupations, business experience and directorships with other companies during the last five years or more. The designation “affiliated”, when used below with respect to a director, means that the director is an officer or employee of the Company or one of its subsidiaries. The designation “independent”, when used below with respect to a director, means that the director is neither an officer of the Company nor a director, officer or employee of a subsidiary of the Company, although the Company may have certain business or professional relationships with the director as discussed in Item 13. Certain Relationships and Related Transactions.
Roz Campisi Beadle, age 53, (Independent) Director since December 2003
Ms. Beadle is Executive Vice President of Unified Housing Foundation and a licensed realtor. She has a background in public relations and marketing. Ms. Beadle is also extremely active in various civic and community services and is currently working with the Congressional Medal of Honor Society and on the Medal of Honor Host City Committee in Gainesville, Texas.
Gene S. Bertcher, age 61, (Affiliated) Director November 1989 to September 1996 and since June 1999
Mr. Bertcher was elected President and Chief Financial Officer effective November 1, 2004. He was elected Chairman and Chief Executive Officer in December 2006. Mr. Bertcher has been Chief Financial Officer and Treasurer of the Company since November 1989 and Executive Vice President from November 1989 until he was elected President. Also, Mr. Bertcher is and will continue to be Executive Vice-President and Chief Financial Officer of American Realty Investors, Inc. (NYSE), Transcontinental Realty Investors, Inc. (NYSE), Income Opportunity Realty Investors, Inc. (AMEX), and Vice President and Treasurer of First Equity Properties, Inc., positions he has occupied since February 2008. He has been a certified public accountant since 1973. No family relationship exists between Mr. Bertcher and any director or executive officer of the Company.
James E. Huffstickler, age 67, (Independent) Director since December 2003
Mr. Huffstickler has been Chief Financial Officer of Sunchase America, Ltd., a multi-state property management company, for more than nineteen years. He is a graduate of the University of South Carolina and was formerly employed by Southmark Management, Inc., a nationwide real estate management company. Mr. Huffstickler has been a certified public accountant since 1976.
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Dan Locklear, age 58, (Independent) Director since December 2003
Mr. Locklear has been Chief Financial Officer of Sunridge Management Group, a real estate management company, for more than five years. Mr. Locklear was formerly employed by Johnstown Management Company, Inc. and Trammel Crow Company. Mr. Locklear has been a certified public accountant since 1981 and a licensed real estate broker in the State of Texas since 1978.
Victor L. Lund, age 81, (Independent) Director since March 1996
Mr. Lund founded Wedgwood Retirement Inns, Inc. (“Wedgwood”) in 1977, which became a wholly owned subsidiary of the Company in 1996. For most of Wedgwood’s existence, Mr. Lund was Chairman of the Board, President and Chief Executive Officer, positions he held until Wedgwood was acquired by the Company. Mr. Lund is President and Chief Executive Officer of Wedgwood Services, Inc., a construction services company not affiliated with the Company.
Board Committees
The Board of Directors held four meetings during 2009. For such year, no incumbent director attended fewer than 75% of the aggregate of (i) the total number of meetings held by the Board during the period for which he or she had been a director, and (ii) the total number of meetings held by all Committees of the Board on which he or she served during the period that he or she served.
The Board of Directors has standing Audit, Compensation and Governance and Nominating Committees. The Audit Committee was formed on December 12, 2003, and its function is to review the Company’s operating and accounting procedures. A Charter of the Audit Committee has been adopted by the Board. The current members of the Audit Committee, all of whom are independent within the SEC regulations, the listing standards of the AMEX and the Company’s Corporate Governance Guidelines are Messrs. Locklear (Chairman), Huffstickler and Lund. Mr. Dan Locklear is qualified as an Audit Committee financial expert within the meaning of SEC regulations, and the Board has determined that he has the accounting and related financial management expertise within the meaning of the listing standards of the AMEX. The Audit Committee met once in 2009.
The Governance and Nominating Committee is responsible for developing and implementing policies and practices relating to the corporate governance, including reviewing and monitoring implementation of the Company’s Corporate Governance Guidelines. In addition, the Committee develops and reviews background information on candidates for the Board and makes recommendations to the Board regarding such candidates. The Committee also prepares and supervises the Board’s annual review of director independence and the Board’s performance and self-evaluation. The Charter of the Governance and Nominating Committee was adopted on October 20, 2004. The members of the Committee are Messrs. Huffstickler (Chairman), Lund and Ms. Beadle. The Governance and Nominating Committee met once in 2009.
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The Board has also formed a Compensation Committee of the Board of Directors, adopted a Charter for the Compensation Committee on October 20, 2004, and selected Ms. Beadle (Chairman) and Messrs. Huffstickler and Locklear as members of that Committee. The Compensation Committee met once in 2009.
The members of the Board of Directors at the date of this Report and the Committees of the Board on which they serve are identified below:

Director | Audit Committee | Governance and Nominating Committee | Compensation Committee
Roz Campisi Beadle |  | ü | Chairman
Gene S. Bertcher |  |  |
James E. Huffstickler | ü | Chairman | ü
Dan Locklear | Chairman |  | ü
Victor L. Lund | ü | ü |

Executive Officers
The following person currently serves as the sole executive officer of the Company: Gene S. Bertcher, Chairman of the Board, President, Chief Executive Officer and Treasurer. His position with the Company is not subject to a vote of stockholders. His age, term of service and all positions and offices with the Company, other principal occupations, business experience and directorships with other companies during the last five years or more are listed under the caption “Directors” above.
In addition to the foregoing officers, the Company has other officers not listed herein who are not considered executive officers.
Code of Ethics
The Board of Directors has adopted a code of ethics entitled “Code of Business Conduct and Ethics” that applies to all directors, officers and employees of the Company and its subsidiaries. In addition, the Company has adopted a code of ethics entitled “Code of Ethics for Senior Financial Officers” that applies to the principal executive officer, president, principal financial officer, chief financial officer, principal accounting officer and controller. The text of these documents is posted on the Company’s internet website address at http://www.newconceptenergy.com and is available in print to any stockholder who requests them.
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Section 16(a) Beneficial Ownership Reporting Compliance
Based solely upon a review of Forms 3, 4 and 5 furnished to the Company pursuant to Rule 16a-3(e) promulgated under the Securities Exchange Act of 1934 (the “Exchange Act“), or upon written representations received by the Company, the Company is not aware of any failure by any director, officer or beneficial owner of more than 10% of the Company’s common stock to file with the Securities and Exchange Commission on a timely basis.
Item 11. Executive Compensation
The following tables set forth the compensation in all categories paid by the Company for services rendered during the fiscal years ended December 31, 2009, 2008 and 2007 by the Chief Executive Officer of the Company and to the other executive officers and Directors of the Company whose total annual salary in 2009 exceeded $100,000, the number of options granted to any of such persons during 2009 and the value of the unexercised options held by any of such persons on December 31, 2009.

SUMMARY COMPENSATION TABLE
|  |  |  |  |  |  | Change in |  |
|  |  |  |  |  | Non- | Pension |  |
|  |  |  |  |  | Equity | Value and |  |
Name |  |  |  |  |  | Incentive | Nonqualified | All |
and |  |  |  |  |  | Plan | Deferred | Other |
Principal |  |  |  | Stock | Option | Compen- | Compensation | Compen- |
Position | Year | Salary | Bonus | Awards | Awards | sation | Earnings | sation | Total
Gene S. Bertcher (1) Chairman, President & Chief Financial Officer | 2009 | $ 197,000 |  |  |  |  |  |  | $ 197,000
2008 | $ 197,000 |  |  |  |  |  |  | $ 197,000
2007 | $ 186,000 |  |  |  |  |  |  | $ 186,000
Doug Wight, President(2) | 2008 | $ 67,000 |  |  |  |  |  |  | $ 67,000

| (1)In February 2008 began providing assistance to a related company which reimburses NCE for 50% of Mr. Bertcher’s total compensation. The salary in the above table represents total compensation before reimbursement.

| (2)Doug Wight joined the Company in September 2008 with an annual salary of $180,000. Effective April 9, 2009 Mr. Wight is no longer with the Company. Mr. Bertcher was reappointed by the Board of Directors as President.

GRANTS OF PLAN-BASED AWARDS
None
OUTSTANDING EQUITY AWARDS AT FISCAL YEAR-END
None
OPTION EXERCISES AND STOCK VESTED
The option to purchase 10,000 shares was exercised in December 2008. The option to purchase 40,000 shares expired in December 2008.
PENSION BENEFITS
None
NONQUALIFIED DEFERRED COMPENSATION
None
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DIRECTOR COMPENSATION
Name | Fees Earned Or Paid in Cash | Stock Awards | Option Awards | Non-Equity Incentive Plan Compensation | Change in Pension Value and Nonqualified Deferred Compensation Earnings | All Other Compensation | Total
Roz Campisi Beadle | $ 10,500 |  |  |  |  |  | $10,500
Gene S. Bertcher | $ — |  |  |  |  |  | $—
James E. Huffstickler | $ 10,500 |  |  |  |  |  | $10,500
Dan Locklear | $ 10,500 |  |  |  |  |  | $10,500
Victor L. Lund | $ 10,500 |  |  |  |  |  | $10,500

MANAGEMENT AND CERTAIN SECURITY HOLDERS
None
Compensation of Directors
The Company pays each non-employee director a fee of $2,500 per year, plus a meeting fee of $2,000 for each board meeting attended. Employee directors serve without compensation.

| Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The following table sets forth, as of March 24, 2010, certain information with respect to all stockholders known by the Company to own beneficially more than 5% of the outstanding common stock, which is the only outstanding class of securities of the Company, except for Series B Preferred Stock (the ownership of which is immaterial), as well as information with respect to the Company’s common stock owned beneficially by each director and current executive officers, whose compensation from the Company in 2009 exceeded $100,000, and by all directors and executive officers as a group. Unless otherwise indicated, each of these stockholders has sole voting and investment power with respect to the shares beneficially owned.

|  | Common Stock |
Name of Beneficial Owner |  | No. of Shares |  |  | Percent of Class* |
Arcadian Energy, Inc.(3)(5) |  |  | 1,313,078 |  |  |  | 67.44 | %
Roz Campisi Beadle |  |  | 100 |  |  |  | ** |
Gene S. Bertcher(2) |  |  | 71,811 |  |  |  | 3.7 | %
Go Green Fuel N.A., L.P. (6) |  |  | 100,000 |  |  |  | 5.14 | %
HKS Investment Corporation(1) |  |  | 108,944 |  |  |  | 5.6 | %
James E. Huffstickler |  |  | — |  |  |  | 0 | %
Dan Locklear |  |  | — |  |  |  | 0 | %
Victor L. Lund |  |  | — |  |  |  | 0 | %
TacCo Financial, Inc.(3)(4) |  |  | 500 |  |  |  | ** |
URC Energy, LLC(3)(5) |  |  | 950,000 |  |  |  | 48.7 | %
All executive officers and directors as a group (five persons) |  |  | 81,911 |  |  |  | 4.2 | %

- 25 -

* Based on 1,946,935 shares of common stock outstanding at March 24, 2010.
** Less than 1%.

(1) | Consists of 108,994 shares of common stock owned by HKS Investment Corporation (“HKS”). According to an original statement on Schedule 13D dated January 9, 2006, the group consists of HKS Investment Corporation, David Hensel, John Kellar and Marshall Stagg, each of whom are deemed to be the beneficial owner of all 108,994 shares. Hensel is stated to be a shareholder, director and President of HKS; Kellar is a shareholder, director, Vice President and Treasurer of HKS; and Stagg is a shareholder, director and Secretary of HKS.

(2) | Consists of 71,811 shares of common stock owned by Mr. Bertcher.

(3) | Based on Amendment 15 to Schedule 13D, amended December 31, 2009, filed by each of these entities. Arcadian Energy, Inc. owns 363,078 shares direct and is the sole member of URC Energy, LLC which owns 950,000 shares. The amended Schedule 13D indicates that these entities, collectively, may be deemed a “Person” within the meaning of Section 13D of the Securities Exchange Act of 1934.

(4) | Consists of 500 shares of common stock. Officers and Directors of TacCo Financial, Inc. (“TFI”) are J.T. Tackett, Director, Chairman and CEO; Wayne Starr, Director, President and Treasurer and Craig E. Landess, Secretary. TFI’s stock is owned by Electrical Networks, Inc. (75%) and Starr Investments (25%).

(5) | The direct owner of the 950,000 shares of common stock is URC Energy, LLC. Under Rule 13d-3 of the Exchange Act, Arcadian Energy, Inc. as the sole member of URC Energy, LLC is deemed to be the beneficial owner of such shares.

(6) | Consists of 100,000 shares of Common Stock owned by Go Green Fuel N.A., L.P. a Texas limited partnership, the sole General Partner of which is GGF North American, LLC, a Texas limited liability company. According to an original statement on Schedule 13D dated December 31, 2009, Go Green Fuel N.A., L.P. acquired 100,000 shares of Common Stock from West Go Green, LLC a Nevada limited liability company at a price of $6.90 per share and Go Green Fuel N.A., LP granted to West Go Green LLC a “Repurchase Option” for a period of three calendar years from December 31, 2009 to repurchase all or any portion of the 100,000 shares purchased at the original purchase price of $6.90 per share, which Repurchase Option may be exercised by West Go Green, LLC or its assignee by written notice given to Go Green Fuel N.A. LP at least two calendar days prior to the date of exercise of the Repurchase Option.

Change in Control
On July 21, 2009, Arcadian Energy, Inc. a Nevada corporation (“Arcadian”) acquired from Syntek West, Inc., a Nevada corporation (“SWI”) (i) 395,078 shares of Common Stock of the Company (approximately 20.29% of the issued and outstanding Common Stock) at an aggregate price of $2,074,160 (approximately $5.25 per share) and (ii) 100% of the Membership Interest of and in URC Energy LLC, a Nevada limited liability company (“URCLLC”) for a purchase price of $5,220,585. URCLLC owns and has owned since May 18, 2008, an aggregate of 950,000 shares of Common Stock of the Company (approximately 48.79% of the issued and outstanding Common Stock). With such acquisition, Arcadian acquired the beneficial ownership of approximately 67% of the issued and outstanding Common Stock of the Company and a change of control of the Company occurred. The basis of control is the aggregate percentage of voting securities of the Company which is now beneficially owned by the “Reporting Persons” (approximately 67.44%) which include URCLLC at 48.79% with 950,000 shares of Common Stock and Arcadian at 18.65% with 363,078 shares of Common Stock.
- 26 -

Item 13. Certain Relationships and Related Transactions, and Director Independence
In July 2006, the Company made an unsecured $1.4 million loan to Eurenergy Resources Corporation (“Eurenergy”), a related party. The loan had an annual interest rate of 8% with principal and interest payable within 30 days after demand, and if not sooner demanded, on July 17, 2007. Effective July 17, 2007, the existing accrued interest was added to the principal balance, which increased the principal balance to $1,487,160, and the maturity date was extended to July 17, 2009. All other terms of the note remained the same. At May 21, 2009, the balance due including accrued interest totaled $1,798,456.
In June of 2008, the Company entered into a letter of credit agreement with Eurenergy. The terms of the agreement call for interest at the prime rate plus two percent. At May 21, 2009, the balance of the note and accrued interest was $2,172,441.
On November 20, 2007, the Company made a $630,000 loan to Prime Income Asset Management, Inc. (“PIAMI”). In 2008, the Company made additional net advances on the loan totaling approximately $6.3 million. The initial loan and the additional advances have been combined into a new loan with interest at the prime rate plus two percent.
On May 21, 2009, PIAMI acquired both Eurenergy notes receivable at face value plus accrued interest totaling $3,970,897. At December 31, 2009, the balance due including accrued interest on the note receivable from PIAMI was $10.9 million.
In November 2007, the Company entered into an agreement with Eurenergy to provide accounting and administrative services at $15,000 per month. As of December 31, 2009, Eurenergy owes the Company $156,900 for such services. In June 2009, the agreement with Eurenergy expired. As of December 31, 2009, the amount receivable from Eurenergy has been fully reserved. The Company entered into a similar agreement with Energy Advisors, LLC in July 2009. As of December 31, 2009, Energy Advisors owes the Company $90,000 for accounting and administrative services.
Except as set forth above, the Reporting Persons do not have any contracts, arrangements, understandings or relationships, legal or otherwise, with any person with respect to any securities of the Issuer, including but not limited to, transfer or voting of any of the securities, finders’ fees, joint ventures, loan or option arrangements, puts or calls, guarantees of profits, divisions of profits or losses, or the giving or withholding of proxies.
It is the policy of the Company that all transactions between the Company and any officer or director, or any of their affiliates, must be approved by non-management members of the Board of Directors of the Company. All of the transactions described above were so approved.
- 27 -

Item 14. Principal Accounting Fees and Services
The following table sets forth the aggregate fees for professional services rendered to the Company for the years 2009 and 2008 by the Company’s principal accounting firm Swalm & Associates, P.C.:

Type of Fees |  | 2009 |  |  | 2008 |
Audit Fees |  | $ | 40,215 |  |  | $ | 27,500 |
Audit Related Fees |  |  | — |  |  |  | — |
Tax Fees |  |  | 8,688 |  |  |  | 7,250 |
All Other Fees |  |  | — |  |  |  | — |
Total Fees |  | $ | 48,903 |  |  | $ | 34,450 |

All services rendered by the principal auditors are permissible under applicable laws and regulations and were pre-approved by either of the Board of Directors or the Audit Committee, as required by law. The fees paid to principal auditors for services described in the above table fall under the categories listed below:
Audit Fees: These are fees for professional services performed by the principal auditor for the audit of the Company’s annual financial statements and review of financial statements included in the Company’s Form 10-Q filings and services that are normally provided in connection with statutory and regulatory filings or engagements.
Audit-Related Fees: These are fees for assurance and related services performed by the principal auditor that are reasonably related to the performance of the audit or review of the Company’s financial statements. These services include attestation by the principal auditor that is not required by statute or regulation and consulting on financial accounting/reporting standards.
Tax Fees: These are fees for professional services performed by the principal auditor with respect to tax compliance, tax planning, tax consultation, returns preparation and reviews of returns. The review of tax returns includes the Company and its consolidated subsidiaries.
All Other Fees: These are fees for other permissible work performed by the principal auditor that does not meet the above category descriptions.
These services are actively monitored (as to both spending level and work content) by the Audit Committee to maintain the appropriate objectivity and independence in the principal auditor’s core work, which is the audit of the Company’s consolidated financial statements.
Financial Information Systems Design and Implementation Fees
Neither Swalm & Associates, P.C. nor Farmer, Fuqua & Huff, P.C. rendered professional services to the Company in 2009 with respect to financial information systems design and implementation.
- 28 -

Under the Sarbanes-Oxley Act of 2002 (the “SO Act”), and the rules of the Securities and Exchange Commission (the “SEC”), the Audit Committee of the Board of Directors is responsible for the appointment, compensation and oversight of the work of the independent auditor. The purpose of the provisions of the SO Act and the SEC rules for the Audit Committee’s role in retaining the independent auditor is two-fold. First, the authority and responsibility for the appointment, compensation and oversight of the auditors should be with directors who are independent of management. Second, any non-audit work performed by the auditors should be reviewed and approved by these same independent directors to ensure that any non-audit services performed by the auditor do not impair the independence of the independent auditor. To implement the provisions of the SO Act, the SEC issued rules specifying the types of services that an independent auditor may not provide to its audit client, and governing the Audit Committee’s administration of the engagement of the independent auditor. As part of this responsibility, the Audit Committee is required to pre-approve the audit and non-audit services performed by the independent auditor in order to assure that they do not impair the auditor’s independence. Accordingly, the Audit Committee has adopted a pre-approval policy of audit and non-audit services (the “Policy”), which sets forth the procedures and conditions pursuant to which services to be performed by the independent auditor are to be pre-approved. Consistent with the SEC rules establishing two different approaches to pre-approving non-prohibited services, the Policy of the Audit Committee covers pre-approval of audit services, audit-related services, international administration tax services, non-U.S. income tax compliance services, pension and benefit plan consulting and compliance services, and U.S. tax compliance and planning. At the beginning of each fiscal year, the Audit Committee will evaluate other known potential engagements of the independent auditor, including the scope of work proposed to be performed and the proposed fees, and the approve or reject each service, taking into account whether services are permissible under applicable law and the possible impact of each non-audit service on the independent auditor’s independence from management. Typically, in addition to the generally pre-approved services, other services would include due diligence for an acquisition that may or may not have been known at the beginning of the year. The Audit Committee has also delegated to any member of the Audit Committee designated by the Board or the financial expert member of the Audit Committee responsibilities to pre-approve services to be performed by the independent auditor not exceeding $25,000 in value or cost per engagement of audit and non-audit services, and such authority may only be exercised when the Audit Committee is not in session.
- 29 -

PART IV
Item 15. Exhibits and Financial Statement Schedules

| (a) |  | The following documents are filed as a part of this report:
| (1) |  | FINANCIAL STATEMENTS: The following financial statements of the Registrant and the Report of Independent Public Accountants therein are filed as part of this Report on Form 10-K:
|  |  | Reports of Swalm & Associates, P.C. & Farmer Fuqua & Huff, P.C.34
|  |  | Consolidated Balance Sheets | 36
|  |  | Consolidated Statement of Operations | 38
|  |  | Consolidated Statements of Cash Flows | 39
|  |  | Consolidated Statement of Changes in Stockholders’ Equity | 41
|  |  | Notes to Consolidated Financial Statements | 42
| (2) |  | FINANCIAL STATEMENT SCHEDULES: Other financial statement schedules have been omitted because the information required to be set forth therein is not applicable, is immaterial or is shown in the consolidated financial statements or notes thereto. |
| (2) |  | EXHIBITS |

The following documents are filed as exhibits (or are incorporated by reference as indicated) into this Report:

Exhibit Designation | Exhibit Description
3.1 | Articles of Incorporation of Medical Resource Companies of America (incorporated by reference to Exhibit 3.1 to Registrant’s Form S-4 Registration Statement No. 333-55968 dated December 21, 1992)
3.2 | Amendment to the Articles of Incorporation of Medical Resource Companies of America (incorporated by reference to Exhibit 3.5 to Registrant’s Form 8-K dated April 1, 1993)

- 30 -

3.3 | Restated Articles of Incorporation of Greenbriar Corporation (incorporated by reference to Exhibit 3.1.1 to Registrant’s Form 10-K dated December 31, 1995)
3.4 | Amendment to the Articles of Incorporation of Medical Resource Companies of America (incorporated by reference to Exhibit to Registrant’s PRES 14-C dated February 27, 1996)
3.5 | Certificate of Decrease in Authorized and Issued Shares effective November 30, 2001 (incorporated by reference to Exhibit 2.1.7 to Registrant’s Form 10-K dated December 31, 2002)
3.6 | Certificate of Designations, Preferences and Rights of Preferred Stock dated May 7, 1993 relating to Registrant’s Series B Preferred Stock (incorporated by reference to Exhibit 4.1.2 to Registrant’s Form S-3 Registration Statement No. 333-64840 dated June 22, 1993)
3.7 | Certificate of Voting Powers, Designations, Preferences and Rights of Registrant’s Series F Senior Convertible Preferred Stock dated December 31, 1997 (incorporated by reference to Exhibit 2.2.2 of Registrant’s Form 10-KSB for the fiscal year ended December 31, 1997)
3.8 | Certificate of Voting Powers, Designations, Preferences and Rights of Registrant’s Series G Senior Non-Voting Convertible Preferred Stock dated December 31, 1997 (incorporated by reference to Exhibit 2.2.3 of Registrant’s Form 10-KSB for the fiscal year ended December 31, 1997)
3.9 | Certificate of Designations dated October 12, 2004 as filed with the Secretary of State of Nevada on October 13, 2004 (incorporated by reference to Exhibit 3.4 of Registrant’s Current Report on Form 8-K for event occurring October 12, 2004)
3.10 | Certificate of Amendment to Articles of Incorporation effective February 8, 2005 (incorporated by reference to Exhibit 3.5 of Registrant’s Current Report on Form 8-K for event occurring February 8, 2005)
3.11 | Certificate of Amendment to Articles of Incorporation effective March 21, 2007 (incorporated by reference to Exhibit 3.13 of Registrant’s Current Report on Form 8-K for event occurring March 21, 2005)
3.12 | Amended and restated bylaws of New Concept Energy, Inc. dated November 18, 2008.
10.1 | Registrant’s 1997 Stock Option Plan (filed as Exhibit 4.1 to Registrant’s Form S-8 Registration Statement, Registration No. 333-33985 and incorporated herein by this reference).

- 31 -

10.2 | Registrant’s 2000 Stock Option Plan (filed as Exhibit 4.1 to Registrant’s Form S-8 Registration Statement, Registration No. 333-50868 and incorporated herein by this reference)
10.3 | Form of Umbrella Agreement between Greenbriar Corporation, James R. Gilley and Jon Harder, Sunwest Management, Inc. et al
14.0 | Code of Ethics for Senior Financial Officers (incorporated by reference to Exhibit 14.0 to Registrant’s Annual Report on Form 10-K for the fiscal year ended December 31, 2003)
21.1* | Subsidiaries of the Registrant
23.2* | Consent of Lee Keeling & Associates, Inc.
31.1* | Rule 13a-14(a) Certification by Principal Executive Officer and Chief Financial Officer
32.1* | Certification of Principal Executive Officer and Chief Financial Officer pursuant to 18 U.S.C. §1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
99.1* | Estimated Reserves and Future Net Reserves Producing and Undeveloped Reserves Oil and Gas Properties Report for 2009

99.2* | Estimated Reserves and Future Net Reserves Producing and Undeveloped Reserves Oil and Gas Properties Report for 2008

*Filed herewith.

- 32 -

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

| NEW CONCEPT ENERGY, INC. |
November 17, 2010 | by: | /s/ Gene S. Bertcher |
|  | Gene S. Bertcher, Principal Executive |
|  | Officer, President and Chief Financial Officer |

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons in the capacities and on the dates indicated.

Signature | Title | Date
/s/ Gene S. Bertcher Gene S. Bertcher | Chairman, President, Principal Executive Officer, Chief Financial Officer and Director | November 17, 2010
/s/ Roz Campisi Beadle Roz Campisi Beadle | Director | November 17, 2010
/s/ James Huffstickler James Huffstickler | Director | November 17, 2010
/s/ Dan Locklear Dan Locklear | Director | November 17, 2010
/s/ Victor L. Lund Victor L. Lund | Director | November 17, 2010

- 33 -

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders
New Concept Energy, Inc., formerly Cabeltel International Corporation
We have audited the accompanying consolidated balance sheet of New Concept Energy, Inc., and subsidiaries, as of December 31, 2009 and 2008, and the related consolidated statements of income, shareholders' equity and cash flows for the years then ended. These consolidated financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the consolidated financial statements based on our audit.
We conducted our audit 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 includes 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 of the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
As described in the notes to the financial statements, New Concept Energy, Inc. has significant balances due from affiliates.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of New Concept Energy, Inc., formerly CableTel Corporation, and subsidiaries as of December 31, 2009 and 2008, and the consolidated results of their operations and their cash flows for the years then ended, in conformity with accounting principles generally accepted in the United States of America.
/s/ Swalm & Associates, P.C.
Plano, Texas
March 31, 2010
- 34 -

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders
New Concept Energy, Inc., formerly Cabeltel International Corporation
We have audited the accompanying consolidated statements of income, shareholders' equity and cash flows of New Concept Energy, Inc., and subsidiaries, for the year then ended December 31, 2007. These consolidated financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the consolidated financial statements based on our audit.
We conducted our audit 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 includes 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 of the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the consolidated financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audit provides a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the consolidated results of operations and cash flows of New Concept Energy, Inc., formerly CableTel Corporation, and subsidiaries for the year December 31, 2007, in conformity with accounting principles generally accepted in the United States of America.
/s/ Farmer Fuqua & Huff, P.C.
Plano, Texas
March 31, 2008
- 35 -

New Concept Energy Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS
(amounts in thousands)

|  | December 31, |
Assets |  | 2009 |  |  | 2008 |
Current assets: |  |  |  |  |  |
Cash and cash equivalents |  | $ | 155 |  |  | $ | 190 |
Accounts receivable from oil and gas sales |  |  | 203 |  |  |  | 353 |
Note and interest receivable – related party |  |  | 11,206 |  |  |  | 10,731 |
Other current assets (including $189 from related parties in 2008) |  |  | 567 |  |  |  | 428 |
Total current assets |  |  | 12,131 |  |  |  | 11,702 |
Oil and natural gas properties (full cost accounting method): |  |  |  |  |  |  |  |
Proved developed and undeveloped oil and gas properties, net of depletion |  |  | 11,372 |  |  |  | 13,022 |
Property and equipment, net of depreciation: |  |  |  |  |  |  |  |
Land, buildings and equipment - oil and gas operations |  |  | 1,337 |  |  |  | 1,291 |
Other |  |  | 149 |  |  |  | 149 |
Total property and equipment |  |  | 1,486 |  |  |  | 1,440 |
Other assets |  |  | 132 |  |  |  | 228 |
Total Assets |  | $ | 25,121 |  |  | $ | 26,392 |

The accompanying notes are an integral part of these statements.
- 36 -

New Concept Energy Inc. and Subsidiaries
CONSOLIDATED BALANCE SHEETS - CONTINUED
(amounts in thousands, except share amounts)

|  | December 31, |
Liabilities And Stockholders’ Equity |  | 2009 |  |  | 2008 |
Current liabilities: |  |  |  |  |  |
Accounts payable – trade |  | $ | 154 |  |  | $ | 202 |
Accrued expenses |  |  | 2,711 |  |  |  | 1,944 |
Total current liabilities |  |  | 2,865 |  |  |  | 2,146 |
Long-term debt: |  |  |  |  |  |  |  |
Notes payable |  |  | 1,198 |  |  |  | 1,026 |
Asset retirement obligation |  |  | 2,450 |  |  |  | 2,334 |
Other long-term liabilities |  |  | 326 |  |  |  | 394 |
Total liabilities |  |  | 6,839 |  |  |  | 5,900 |
Stockholders’ equity: |  |  |  |  |  |  |  |
Preferred stock, Series B |  |  | 1 |  |  |  | 1 |
Common stock, $.01 par value; authorized, 100,000,000 |  |  |  |  |  |  |  |
shares; issued and outstanding, 1,946,939 shares at |  |  |  |  |  |  |  |
December 31, 2009 and 2008 |  |  | 20 |  |  |  | 20 |
Additional paid-in capital |  |  | 58,838 |  |  |  | 58,838 |
Accumulated deficit |  |  | (40,577 | ) |  |  | (38,367 | )
|  |  | 18,282 |  |  |  | 20,492 |
Total Liabilities & Equity |  | $ | 25,121 |  |  | $ | 26,392 |

The accompanying notes are an integral part of these statements.
- 37 -

New Concept Energy, Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF OPERATIONS
(amounts in thousands, except per share amounts)

|  | Year Ended |
|  | December 31, |
|  | 2009 |  |  | 2008 |  |  | 2007 |
Revenue |  |  |  |  |  |  |  |  |
Oil and gas operations, net of royalties |  | $ | 1,241 |  |  | $ | 672 |  |  | $ | — |
Real estate operations |  |  | 2,857 |  |  |  | 2,888 |  |  |  | 2,984 |
|  |  | 4,098 |  |  |  | 3,560 |  |  |  | 2,984 |
Operating expenses |  |  |  |  |  |  |  |  |  |  |  |
Oil and gas operations |  |  | 1,516 |  |  |  | 496 |  |  |  | — |
Real estate operations |  |  | 1,334 |  |  |  | 1,400 |  |  |  | 1,315 |
Lease expense |  |  | 958 |  |  |  | 954 |  |  |  | 845 |
Corporate general and administrative |  |  | 1,207 |  |  |  | 852 |  |  |  | 796 |
Accretion of asset retirement obligation |  |  | 117 |  |  |  | — |  |  |  | — |
Impairment of natural gas and oil properties |  |  | 1,695 |  |  |  | — |  |  |  | — |
|  |  | 6,827 |  |  |  | 3,702 |  |  |  | 2,956 |
Operating earnings (loss) |  |  | (2,729 | ) |  |  | (142 | ) |  |  | 28 |
Other income (expense) |  |  |  |  |  |  |  |  |  |  |  |
Interest income |  |  | 574 |  |  |  | 785 |  |  |  | 112 |
Interest expense |  |  | (123 | ) |  |  | (270 | ) |  |  | (73 | )
Gain on sale of assets, net |  |  | — |  |  |  | 16,432 |  |  |  | 750 |
Other income, net |  |  | 68 |  |  |  | 464 |  |  |  | 142 |
|  |  | 519 |  |  |  | 17,411 |  |  |  | 931 |
Earnings from continuing operations |  |  | (2,210 | ) |  |  | 17,269 |  |  |  | 959 |
Provision for income taxes |  |  | — |  |  |  | (1,774 | ) |  |  | (270 | )
Net income from continuing operations |  |  | (2,210 | ) |  |  | 15,495 |  |  |  | 689 |
Discontinued operations (net of income taxes) |  |  |  |  |  |  |  |  |  |  |  |
Loss from operations |  |  | — |  |  |  | — |  |  |  | (101 | )
Gain (loss) from sale of assets |  |  | — |  |  |  | — |  |  |  | (526 | )
Net loss from discontinued operations |  |  | — |  |  |  | — |  |  |  | (627 | )
Net income applicable to common shares |  | $ | (2,210 | ) |  | $ | 15,495 |  |  | $ | 62 |

Earnings (loss) per common share – basic |  |  |  |  |  |  |  |  |
Continuing operations |  | $ | (1.27 | ) |  | $ | 8.92 |  |  | $ | 0.70 |
Discontinued operations |  |  | — |  |  |  | — |  |  |  | (0.64 | )
Net earnings (loss) per share |  | $ | (1.27 | ) |  | $ | 8.92 |  |  | $ | 0.06 |
Weighted average common and equivalent shares outstanding – basic |  |  | 1,737 |  |  |  | 1,737 |  |  |  | 987 |

The accompanying notes are an integral part of these statements.
- 38 -

New Concept Energy Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS
(amounts in thousands)

|  | Year ended December 31, |
|  | 2009 |  |  | 2008 |  |  | 2007 |
Cash flows from operating activities |  |  |  |  |  |  |  |  |
Net income |  | $ | (2,210 | ) |  | $ | 15,495 |  |  | $ | 62 |
Adjustments to reconcile net income to net cash provided by (used in) operating activities |  |  |  |  |  |  |  |  |  |  |  |
Depreciation and amortization |  |  | 61 |  |  |  | 59 |  |  |  | 47 |
Depletion of minerals |  |  | 298 |  |  |  | 112 |  |  |  | — |
Impairment of natural gas and oil properties |  |  | 1,695 |  |  |  | — |  |  |  | — |
Accretion of asset retirement obligation |  |  | 117 |  |  |  | — |  |  |  | — |
Write-off of affiliate receivable |  |  | 157 |  |  |  | — |  |  |  | — |
Net loss from discontinued operations |  |  | — |  |  |  | — |  |  |  | 101 |
Gain) loss on sale of discontinued operations |  |  | — |  |  |  | — |  |  |  | 526 |
(Gain) loss on sale of assets |  |  | —15,835 |  |  |  | (16,432 | )15,835 |  |  | — |
Change in deferred tax asset |  |  | — |  |  |  | 250 |  |  |  | 241 |
Changes in operating assets and liabilities |  |  |  |  |  |  |  |  |  |  |  |
Other current and non-current assets |  |  | (153 | ) |  |  | (873 | ) |  |  | (44 | )
Accounts payable and other liabilities |  |  | 771 |  |  |  | 1,816 |  |  |  | (184 | )
Net cash provided by (used) in operating activities |  |  | 736 |  |  |  | 427 |  |  |  | 749 |
Cash flows from investing activities |  |  |  |  |  |  |  |  |  |  |  |
Funding of notes receivable |  |  | (372 | ) |  |  | (23,287 | ) |  |  | (630 | )
Investment mineral rights |  |  | (344 | ) |  |  | — |  |  |  | — |
Purchase of property and equipment, net |  |  | (107 | ) |  |  | (1,354 | ) |  |  | (49 | )
Net repayment of notes receivable |  |  | — |  |  |  | 14,791 |  |  |  | — |
Purchase of oil and gas subsidiary |  |  | — |  |  |  | (10,808 | ) |  |  | — |
Proceeds from sale of mineral rights |  |  | — |  |  |  | 23,288 |  |  |  | — |
Net cash provided by (used in) investing activities |  |  | (823 | ) |  |  | 2,630 |  |  |  | (679 | )
Cash flows from financing activities |  |  |  |  |  |  |  |  |  |  |  |
Proceeds from notes payable |  |  | 58 |  |  |  | — |  |  |  | — |
Proceeds from common stock issuance |  |  | — |  |  |  | 2,856 |  |  |  | — |
Debt incurred in connection with acquisition |  |  | — |  |  |  | 1,026 |  |  |  | — |
Payments on debt |  |  | (6 | ) |  |  | (6,921 | ) |  |  | — |
Net cash provided by (used in) financing activities |  |  | 52 |  |  |  | (3,039 | ) |  |  | — |
Cash flows from discontinued operations |  |  |  |  |  |  |  |  |  |  |  |
Cash (used in) operating activities |  |  | — |  |  |  | — |  |  |  | (222 | )
Net cash provided by (used in) discontinued operations |  |  | — |  |  |  | — |  |  |  | (222 | )
Net increase (decrease) in cash and cash equivalents |  |  | (35 | ) |  |  | 18 |  |  |  | (152 | )
Cash and cash equivalents at beginning of year |  |  | 190 |  |  |  | 172 |  |  |  | 324 |
Cash and cash equivalents at end of year |  | $ | 155 |  |  | $ | 190 |  |  | $ | 172 |

The accompanying notes are an integral part of these statements
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New Concept Energy Inc. and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS- CONTINUED
(amounts in thousands)

|  | Year ended December 31, |
|  | 2009 |  |  | 2008 |  |  | 2007 |
Supplemental information on cash flows is as follows: |  |  |  |  |  |  |  |  |
Interest paid |  |  | — |  |  |  | — |  |  |  | — |
Non-cash investing and financing activities: |  |  |  |  |  |  |  |  |  |  |  |
Acquisition of leases for mineral rights |  |  | — |  |  |  | — |  |  |  | (6,848 | )
Notes payable for acquisition of mineral rights |  |  | — |  |  |  | — |  |  |  | 6,848 |

The accompanying notes are an integral part of this statement.
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New Concept Energy Inc. and Subsidiaries
CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS’ EQUITY
(amounts in thousands)

|  | Series B Preferred stock |  |  | Series J Preferred stock |  |  | Series J Preferred Stock Contra Equity |  |  | Common Stock |  |  | Additional paid in |  |  | Accum- ulated |  |  |  |
|  | Shares |  |  | Amount |  |  | Shares |  |  | Amount |  |  | Shares |  |  | Amount |  |  | Shares |  |  | Amount |  |  | capital |  |  | deficit |  |  | Total |
Balance at January 1, 2007 |  |  | 1 |  |  | $ | 11 |  |  |  | — |  |  | $ | — |  |  |  | — |  |  | $ | — |  |  |  | 987 |  |  | $ | 10 |  |  | $ | 55,992 |  |  | $ | (53,924 | ) |  | $ | 2,079 |
Net Income |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 62 |  |  |  | 62 |
Balance at December 31, 2007 |  |  | 1 |  |  |  | 1 |  |  |  | — |  |  |  | — |  |  |  | — |  |  |  | — |  |  |  | 987 |  |  |  | 10 |  |  |  | 55,992 |  |  |  | (53,862 | ) |  |  | 2,141 |
Exercised stock option |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 10 |  |  |  |  |  |  |  | 5 |  |  |  |  |  |  |  | 5 |
Issue of stock |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 950 |  |  |  | 10 |  |  |  | 2,840 |  |  |  |  |  |  |  | 2,850 |
Net Income |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 15,495 |  |  |  | 15,495 |
Balance at December 31, 2008 |  |  | 1 |  |  |  | 1 |  |  |  | — |  |  |  | — |  |  |  | — |  |  |  | — |  |  |  | 1,947 |  |  |  | 20 |  |  |  | 58,838 |  |  |  | (38,367 | ) |  |  | 20,492 |
Net Income |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | (2,210 | ) |  |  | (2,210 | )
Balance at December 31, 2009 |  |  | 1 |  |  | $ | 11 |  |  |  | — |  |  | $ | — |  |  |  | — |  |  | $ | — |  |  |  | 1,947 |  |  | $ | 20 |  |  | $ | 58,838 |  |  | $ | (40,577 | ) |  | $ | 18,282 |

The accompanying notes are an integral part of this statement.
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New Concept Energy Inc. and Subsidiaries
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2009
The accompanying Consolidated Financial Statements of New Concept Energy, Inc. and consolidated entities were prepared in conformity with accounting principles generally accepted in the United States of America, the most significant of which are described in NOTE B. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES. The Notes to Consolidated Financial Statements are an integral part of these Consolidated Financial Statements. The data presented in the Notes to Consolidated Financial Statements are as of December 31, of each year and for the year then ended, unless otherwise indicated. Dollar amounts in tables are in thousands, except per share amounts.
Certain balances for 2007 and 2008 have been reclassified to conform to the 2009 presentation.
NOTE A – BUSINESS DESCRIPTION AND PRESENTATION
Acquisition Of Carl E. Smith Companies
Effective September 1, 2008, the Company completed the acquisition of certain entities, mineral interests and related assets through entities named Carl E. Smith, Inc., a West Virginia corporation, two of its affiliates, Carl E. Smith Petroleum, Inc. and Carl E. Smith Real Estate, Inc. and other privately owned related assets (collectively “CESI”). Immediately after the acquisition, all of the acquired entities and assets were merged into Carl E. Smith, Inc., the name of which was changed to Mountaineer State Energy, Inc. (“Mountaineer”) which became a wholly-owned subsidiary of NCE. The assets acquired include 94 producing gas wells, 121 non-producing wells and related equipment, mineral leases covering 20,000 acres located in Athens and Meigs Counties in Ohio as well as Calhoun, Jackson and Roane Counties in West Virginia. In addition to the wells and mineral leases, the acquisition included a complex covering approximately 41 acres of land with 8,000 square feet of office and storage buildings, an adjacent 12 acres site with a 24 stall horse barn, machinery and equipment in excess of the needs of the gas operation and approximately $1.5 million in cash.
The entities involved were the subject of bankruptcy proceedings in the Southern District of West Virginia originally filed in 2003 styled In Re Carl E. Smith, Inc., Case No. 03-22274 (Chapter 11) pending in the United Stated Bankruptcy Court for the Southern District of West Virginia, which was substantively consolidated with Carl E. Smith Real Estate, Inc., Case No. 03-22298 and Carl E. Smith Petroleum, Inc., Case No. 08-20022 (the “Bankruptcy Proceedings”). Pursuant to the Bankruptcy Proceedings, a subsidiary of NCE acquired a claim of an independent third party, and engaged in a bidding contest which resulted in the Court awarding NCE the bid on August 6, 2008, which was confirmed August 16, 2008, but various documents and instruments confirming the matter were not completed until September 19, 2008. Pursuant to the confirmed Plan of Reorganization, NCE paid all existing debt to third parties of approximately $5 million, paid cash of $7.3 million dollars to certain shareholders and paid or will pay approximately $1.6 million dollars in fees and bankruptcy related costs.
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In addition, the Company entered into several agreements in which the Company agreed to payout two former shareholders and a family member.
The agreements all provide that bankruptcy administrative costs incurred over $500,000 would be reimbursed to NCE prior to any payments being made on the notes. The administrative costs incurred over $500,000 were approximately $1.1 million. The agreements further provide that NCE can reduce the note payments for any amounts that might be recovered by the IRS should they choose to audit CESI for period prior to the acquisition.
In the first two similar agreements two shareholders are to receive a total of $1,760,000 less administrative costs noted above. The Company is to make payments to each former shareholder in the amount of $1,000 a week for the next 17 years. The allocation of the administrative costs to each specific agreement is dependent on future events however the Company does not anticipate making any cash payments for five years.
The second agreement was in the amount of $600,000 and requires the Company should make payments equal to 100% of the available cash flow from the acquired entities. The entire obligation is required to be paid within five years. Available cash flow is to be determined by NCE based upon Mountaineer State Energy’s actual as well as projected cash needs. NCE anticipates that almost all of this obligation will be used to repay a portion of the reimbursable administrative costs.
The third agreement was in the amount of $1,000,000 and state the Company should make payments in the amount of 75% of available funds from the operation of the business under terms similar to the note above. However, the payments do not begin until the second agreement is fully funded. The agreement further provides that it be paid within seven years.
The Company has evaluated the above notes and after factoring the administrative cost reimbursement, imputing a 10% interest rate, and accreting interest since acquisition, has valued the above obligations at $1,198,000 at December 31, 2009.
In 2002, the Internal Revenue Service (“IRS”) commenced an audit of the CESI and its related companies. This audit was halted in its early stages during which time the Justice Department began a review and subsequent prosecution of certain individual owners and related individuals of CESI. It is unknown as to whether, at this point, the IRS will choose to renew its audit of the Company for any years prior to our acquisition of CESI. The bankruptcy plan provides that the IRS has two years from the approval of the plan of reorganization to complete an audit should it choose to do so. The bankruptcy code provides certain limitations as to how far back the IRS can go in determining any claims against CESI. We believe that should the IRS complete an audit for the years legally available for a claim the IRS would find no material adjustments. Further, should the IRS be successful in any claims against CESI, any payments made by the Company would reduce future payments due the previous owners, per the terms of the acquisition.
Certain individuals have filed administrative claims in the bankruptcy court totaling approximately $400,000. Should any of these claims be successful, any obligation paid by the Company would reduce future payments due the previous owners, per the terms of the acquisition.
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The purchase price of $13,850,000 was paid in cash as follows.
The computation of the purchase price is:

Cash paid to all sellers |  | $ | 7,300 |
Cash paid to creditors |  |  | 5,000 |
Cash paid in fees and bankruptcy related costs |  |  | 1,550 |
Total cash cost |  | $ | 13,850 |

The details of the purchase price allocation are as follows:
Carl E. Smith etal
Opening Balance Sheet
September 1, 2008
(000’s omitted)
Assets

Cash |  | $ | 1,586 |
A/R Receivable |  |  | 482 |
Oil & Gas Properties |  |  | 13,134 |
Property and Equipment |  |  | 1,363 |
Other Assets |  |  | 807 |
Total Assets |  | $ | 17,372 |

Liabilities & Shareholder’s Equity

Accounts Payable |  | $ | 162 |
Long Term Debt |  |  | 1,026 |
Asst Retirement Obligation |  |  | 2,334 |
Equity |  |  | 13,850 |
Total Liabilities & Shareholders Equity |  | $ | 17,372 |

Nature of Operations
New Concept operates oil and gas wells and mineral leases in Athens and Meigs Counties in Ohio and in Calhoun, Jackson and Roane Counties in West Virginia through its wholly owned subsidiaries Mountaineer State Energy, LLC and Mountaineer State Operations, LLC.
NCE also leases and operates a retirement community in King City Oregon, with a capacity of 114 residents.
NOTE B - SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
A summary of the significant accounting policies applied in the preparation of the accompanying consolidated financial statements follows:
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Principles of Consolidation
The consolidated financial statements include the accounts of New Concept Energy, Inc. and its majority-owned subsidiaries (collectively, the “Company”, New Concept or “NCE”) and are prepared on the basis of accounting principles generally accepted in the United States of America. All significant intercompany transactions and accounts have been eliminated.
Depreciation and Amortization
Depreciation is provided for in amounts sufficient to relate the cost of property and equipment to operations over their estimated service lives, ranging from 3 to 40 years. Depreciation is computed by the straight-line method. Depreciation and amortization expense, included in operations expenses, was $83,000, $60,000, and $48,000 for 2009, 2008, and 2007 respectively.
Depletion of Mineral Rights
The Company recorded depletion of mineral rights of $298,000 in 2009 and $112,000 in 2008. No such costs were incurred in 2007.
Segments
The Company operates two primary business segments; oil and gas operations and retirement facilities. Segment data is provided in “Note N” to these consolidated financial statements.
Major Purchaser
The Company has one primary purchaser of its oil natural gas, which in 2009 comprised 89 percent of total sales. While there is an available market for crude oil and natural gas production, we cannot be assured that the loss of this purchaser would not have a material impact on the Company.
Oil and Gas Reserves
Our proved oil and gas reserves are estimated by independent petroleum engineers. Reserve engineering is a subjective process that is dependent upon the quality of available data and the interpretation thereof, including evaluations and extrapolations of well flow rates and reservoir pressure. Estimates by different engineers often vary, sometimes significantly. In addition, physical factors such as the results of drilling, testing and production subsequent to the date of an estimate, as well as economic factors such as changes in product prices, may justify revision of such estimates. Because proved reserves are required to be estimated using recent prices of the evaluation, estimated reserve quantities can be significantly impacted by changes in product prices.
Depreciation, depletion and amortization (“DD&A”) of producing properties is computed on the unit-of-production method based on estimated proved oil and gas reserves. While total DD&A expense for the life of a property is limited to the property’s total cost, proved reserve revisions result in a change in timing of when DD&A expense is recognized. Downward revisions of proved reserves result in an acceleration of DD&A expense, while upward revisions tend to lower the rate of DD&A expense recognition.
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The standardized measure of discounted future net cash flows and changes in such cash flows are prepared using assumptions required by the Financial Accounting Standards Board and the Securities and Exchange Commission. Such assumptions include using recent oil and gas prices and year-end costs for estimated future development and production expenditures. Discounted future net cash flows are calculated using a 10% rate. Changes in any of these assumptions could have a significant impact on the standardized measure. Accordingly, the standardized measure does not represent management’s estimated current market value of proved reserves.
Full cost accounting
The Company uses the full cost method of accounting for its investment in oil and natural gas properties. Under this method of accounting, all costs of acquisition, exploration and development of oil and natural gas properties (including such costs as leasehold acquisition costs, geological expenditures, dry hole costs, tangible and intangible development costs and direct internal costs) are capitalized as the cost of oil and natural gas properties when incurred.
The full cost method requires the Company to calculate quarterly, by cost center, a “ceiling,” or limitation on the amount of properties that can be capitalized on the balance sheet. To the extent capitalized costs of oil and natural gas properties, less accumulated depletion and related deferred taxes exceed the sum of the discounted future net revenues of proved oil and natural gas reserves, the lower of cost or estimated fair value of unproved properties subject to amortization, the cost of properties not being amortized, and the related tax amounts, such excess capitalized costs are charged to expense. Beginning December 31, 2009, full cost companies use the unweighted arithmetic average first day of the month price for oil and natural gas for the 12-month period preceding the calculation date to calculate the future net revenues of proved reserves. Prior to December 31, 2009, companies used the price in effect at the calculation date and had the option, under certain circumstances, to elect to use subsequent commodity prices if they increased after the calculation date.
At December 31, 2009, the Company’s net book value of oil and natural gas properties exceeded the ceiling amount based on the unweighted arithmetic average of the first day of each month for the 12-month period ended December 31, 2009. As a result, the Company recorded a full cost ceiling adjustment before income taxes of approximately $1.7 million.
The Company assesses any unproved oil and gas properties on an annual basis for possible impairment or reduction in value. The Company assesses properties on an individual basis or as a group if properties are individually insignificant. The assessment includes consideration of the following factors, among others: intent to drill; remaining lease term; geological and geophysical evaluations; drilling results and activity; the assignment of proved reserves; and the economic viability of development if proved reserves are assigned. During any period in which these factors indicate an impairment of unproved properties not subject to amortization, the associated costs incurred to date for such properties are then included in unproved properties subject to amortization.
Gas gathering assets
Gas gathering assets are capitalized as part of the depletable pool and ratably charged to earnings along with other capitalized exploration, drilling and development costs.
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Office and field equipment
Office and field equipment are capitalized at cost and depreciated on a straight line basis over their estimated useful lives. Office and field equipment useful lives range from 5 to 30 years.
Revenue recognition and gas imbalances
We use the sales method of accounting for oil and natural gas revenues. Under the sales method, revenues are recognized based on actual volumes of oil and natural gas sold to purchasers. Gas imbalances at December 31, 2009 were not significant. New Concept also follows the sales method of accounting for natural gas production imbalances and would recognize a liability if the existing proved reserves were not adequate to cover an imbalance.
Accounting for Leases
Leases of property, plant and equipment where the Company assumes substantially all the benefits and risks of ownership are classified as finance leases. Finance leases are capitalized at the estimated present value of the underlying lease payments. Each lease payment is allocated between the liability and finance charges so as to achieve a constant rate on the finance balance outstanding. The corresponding rental obligations, net of finance charges, are included in other long-term payables. The interest element of the finance charge is charged to the income statement over the lease period. Property, plant and equipment acquired under finance leasing contracts are depreciated over the useful life of the asset.
Leases of assets under which all the risks and benefits of ownership are effectively retained by the lessor are classified as operating leases. Payments made under operating leases are charged to the income statement on a straight-line basis over the period of the lease. When an operating lease is terminated before the lease period has expired, any payment required to be made to the lessor by way of penalty is recognized as an expense in the period in which termination takes place.
Revenue Recognition
Rental income for residential property leases is recorded when due from residents and is recognized monthly as it is earned, which is not materially different than on a straight-line basis as lease terms are generally for periods of one year or less.
Revenues are recognized when products are shipped or services are provided to customers, title is transferred, the sales price is fixed or determinable and collectability is reasonably assured. Costs associated with revenues are recorded in cost of revenues. Production volumes of natural gas are sold immediately and transported via pipeline. Royalties on the production of natural gas either paid in cash or settled through the delivery of volumes. New Concept includes royalties in its revenues and cost of revenues when settlement of the royalties is paid in cash, while royalties settled by the delivery of volumes are excluded from revenues and cost of revenues.
New Concept follows the sales method of accounting for natural gas production imbalances and would recognize a liability if the existing proved reserves were not adequate to cover an imbalance.
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Use of Estimates
In preparing financial statements in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and revenues and expenses during the reporting period. Actual results could differ from those estimates.
Cash Equivalents
The Company considers all short-term deposits and money market investments with a maturity of less than three months to be cash equivalents.
Other Intangible Assets
The cost of acquired patents, trademarks and licenses is capitalized and amortized using the straight-line method over their useful lives. The carrying amount of each intangible asset is reviewed annually and adjusted for permanent impairment where it is considered necessary.
Impairment of Notes Receivable
Notes receivable are identified as impaired when it is probable that interest and principal will not be collected according to the contractual terms of the note agreements. The accrual of interest is discontinued on such notes, and no income is recognized until all past due amounts of principal and interest are recovered in full.
Impairment of Long-Lived Assets
The Company reviews its long-lived assets and certain identifiable intangibles for impairment when events or changes in circumstances indicate that the carrying amount of the assets may not be recoverable. In reviewing recoverability, the Company estimates the future cash flows expected to result from use of the assets and eventually disposing of them. If the sum of the expected future cash flows (undiscounted and without interest charges) is less than the carrying amount of the asset, an impairment loss is recognized based on the asset’s fair value.
The Company determines the fair value of assets to be disposed of and records the asset at the lower of fair value less disposal costs or carrying value. Assets are not depreciated while held for disposal.
Stock Options
The Company follows Statement of Financial Accounting Standards No. 123(R), “Share-Based Payment” (“SFAS 123R”) for its stock options. The effect of SFAS 123R is immaterial to the Company’s financial statements.
Sales of Real Estate
Gains on sales of real estate are recognized to the extent permitted by Statement of Financial Accounting Standards No. 66, “Accounting for Sales of Real Estate” (“SFAS No. 66”). Until the requirements of SFAS No. 66 have been met for full profit recognition, sales are accounted for by the installment or cost recovery method, whichever is appropriate.
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Real Estate Held for Sale
Statement of Financial Accounting Standards No. 144 (“SFAS No. 144”) requires that properties held for sale be reported at the lower of carrying amount or fair value less costs of sale. If a reduction in a held for sale property’s carrying amount to fair value less costs of sale is required, a provision for loss is recognized by a charge against earnings. Subsequent revisions, either upward or downward, to a held for sale property’s estimated fair value less costs of sale are recorded as an adjustment to the property’s carrying amount, but not in excess of the property’s carrying amount when originally classified as held for sale. A corresponding charge against or credit to earnings is recognized. Properties held for sale are not depreciated.
Asset Retirement Obligation
The Company records an asset retirement obligation liability on the consolidated balance sheets and capitalizes a portion of the cost in “Oil and natural gas properties” during the period in which the obligation is incurred. The asset retirement obligation is further described in Note Q.
Recent Accounting Pronouncements
FASB Accounting Standards Codification. The Company presents its financial statements in accordance with generally accepted accounting principles in the United States (“GAAP”). In June 2009, the Financial Accounting Standards Board (“FASB”) completed its accounting guidance codification project. The FASB Accounting Standards Codification (“ASC”) became effective for the Company’s financial statements issued subsequent to June 30, 2009 and is the single source of authoritative accounting principles recognized by the FASB to be applied by nongovernmental entities in the preparation of financial statements in conformity with GAAP.
In August 2009, the FASB issued Accounting Standards Update (ASU) No. 2009-05, Fair Value Measurements and Disclosures (ASU 2009-05). ASU 2009-05 amends Subtopic 820-10, Fair Value Measurements and Disclosures, to provide guidance on the fair value measurement of liabilities. ASU 2009-05 provides clarification for circumstances in which a quoted price in an active market for the identical liability is not available. ASU 2009-05 is effective for interim and annual periods beginning after August 26, 2009. The Company adopted the provisions of ASU 2009-05 for the period ended December 31, 2009. There was no impact on the Company’s operating results, financial position or cash flows.
In June 2009, the FASB issued ASU No. 2009-01, Generally Accepted Accounting Principles (ASU 2009-01). ASU 2009-01 establishes “The FASB Accounting Standards Codification,” or Codification, which became the source of authoritative GAAP recognized by the FASB to be applied by nongovernmental entities. On the effective date, the Codification superseded all then-existing non-SEC accounting and reporting standards. All other non-grandfathered non-SEC accounting literature not included in the Codification will become non-authoritative. ASU 2009-01 is effective for interim and annual periods ending after September 15, 2009. The Company adopted the provisions of ASU 2009-01 for the period ended September 30, 2009. There was no impact on the Company’s operating results, financial position or cash flows.
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In May 2009, the FASB issued SFAS No. 165, Subsequent Events (ASC 855) to establish general standards of accounting for and disclosure of events that occur after the balance sheet date but before financial statements are issued or are available to be issued. ASC 855 is effective for interim and annual reporting periods ending after June 15, 2009. The Company adopted the provisions of ASC 855 for the period ended June 30, 2009. There was no impact on the Company’s operating results, financial position or cash flows.
In April 2009, the FASB issued FASB Staff Position (FSP) No. FAS 107-1 and Accounting Principles Board (APB) 28-1, Interim Disclosures about Fair Value of Financial Instruments (ASC 825-10-65) to change the reporting requirements on certain fair value disclosures of financial instruments to include interim reporting periods. The Company adopted ASC 825-10-65 in the second quarter of 2009. There was no impact on the Company’s operating results, financial position or cash flows; however additional disclosures were added to the accompanying notes to the consolidated financial statements for the Company’s fair value of financial instruments.
In April 2009, the FASB issued FSP No. FAS 115-2 and FAS 124-2, Recognition and Presentation of Other-Than-Temporary Impairments, (ASC 320-10-65), to expand other-than-temporary impairment guidance for debt securities to enhance the application of the guidance and improve the presentation and disclosure of other-than temporary impairments on debt and equity securities within the financial statements. The adoption of ASC 320-10-65 in the second quarter of 2009 did not have a significant impact on the Company’s operating results, financial position or cash flows.
In April 2009, the FASB issued FSP No. FAS 157-4, Determining Fair Value When the Volume and Level of Activity for the Asset or Liability Have Significantly Decreased and Identifying Transactions That Are Not Orderly, (ASC 820-10-65) to provide additional guidance for estimating fair value when the volume and level of activity for an asset or liability has significantly decreased. In addition, ASC 820-10-65 includes guidance on identifying circumstances that indicate a transaction is not orderly. The adoption of ASC 820-10-65 in the second quarter of 2009 did not have a significant impact on the Company’s operating results, financial position or cash flows.
In December 2008, the SEC issued Release No. 33-8995, Modernization of Oil and Gas Reporting (ASC 2010-3), which amends the oil and gas disclosures for oil and gas producers contained in Regulations S-K and S-X, as well as adding a section to Regulation S-K (Subpart 1200) to codify the revised disclosure requirements in Securities Act Industry Guide 2, which is being eliminated. The goal of Release No. 33-8995 is to provide investors with a more meaningful and comprehensive understanding of oil and gas reserves. Energy companies affected by Release No. 33-8995 are now required to price proved oil and gas reserves using the unweighted arithmetic average of the price on the first day of each month within the 12-month period prior to the end of the reporting period, unless prices are defined by contractual arrangements, excluding escalations based on future conditions. SEC Release No. 33-8995 is effective beginning for financial statements for fiscal years ending on or after December 31, 2009. The impact on the Company’s operating results, financial position and cash flows has been recorded in the financial statements; additional disclosures were added to the accompanying notes to the consolidated financial statements for the Company’s supplemental oil and gas disclosure. See Note P – Supplementary Financial Information on Oil and Natural Gas Exploration, Development and Production Activities for more details.
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In January 2010, the FASB issued FASB Accounting Standards Update (ASU) No. 2010-03 Oil and Gas Estimations and Disclosures (ASU 2010-03). This update aligns the current oil and natural gas reserve estimation and disclosure requirements of the Extractive Industries Oil and Gas topic of the FASB Accounting Standards Codification (ASC Topic 932) with the changes required by the SEC final rule ASC 2010-3, as discussed above, ASU 2010-03 expands the disclosures required for equity method investments, revises the definition of oil- and natural gas-producing activities to include nontraditional resources in reserves unless not intended to be upgraded into synthetic oil or natural gas, amends the definition of proved oil and natural gas reserves to require 12-month average pricing in estimating reserves, amends and adds definitions in the Master Glossary that is used in estimating proved oil and natural gas quantities and provides guidance on geographic area with respect to disclosure of information about significant reserves. ASU 2010-03 must be applied prospectively as a change in accounting principle that is inseparable from a change in accounting estimate and is effective for entities with annual reporting periods ending on or after a change in accounting estimate and is effective for entities with annual reporting periods ending on or after December 31, 2009. The Company adopted ASU 2010-03 effective December 31, 2009. See Note P – Supplementary Financial Information on Oil and Natural Gas Exploration, Development and Production Activities for more details.
In March 2008, the FASB issued SFAS No. 161, Disclosures about Derivative Instruments and Hedging Activities—an amendment of FASB Statement No. 133 (ASC 815-10-65). ASC 815-10-65 requires entities that utilize derivative contracts to provide qualitative disclosures about their objectives and strategies for using such instruments, as well as any details of credit-risk-related contingent features contained within derivatives. ASC 815-10-65 also requires entities to disclose additional information about the amounts and location of derivatives located within the financial statements, how the provisions of ASC 815 have been applied, and the impact that hedges have on an entity’s operating results, financial position or cash flows. The Company adopted ASC 815-10-65 on January 1, 2009. There was no impact on the Company’s operating results, financial position or cash flows.
In December 2007, the FASB issued SFAS No. 141 (Revised 2007), Business Combinations (ASC 805), and SFAS No. 160, Accounting and Reporting of Noncontrolling Interest in Consolidated Financial Statements, an amendment of ARB No. 51 (ASC 810-10-65). ASC 805 and ASC 810-10-65 significantly change the accounting for and reporting of business combination transactions and noncontrolling (minority) interests within the financial statements. ASC 805 provides additional definitions, such as the definition of the acquirer in a purchase and improvements in the application of how the acquisition method is applied. ASC 810-65 changes the accounting and reporting for minority interests, which are re-characterized as non-controlling interests, and classified as a component of equity. The Company adopted ASC 805 and ASC 810-10-65 on January 1, 2009. There was no impact on the Company’s operating results, financial position or cash flows; however if the Company enters into future business combinations, certain transaction related expenses may be recorded within the Company’s operating results which could reduce its current period net income or increase its net loss. Additionally, valuation of certain assets may be different than under the old accounting standards.
Effective January 1, 2009, the Company adopted FSP No. FAS 157-2, Effective Date of FASB Statement No. 157 (ASC 820-10-55). ASC 820-10-55 delayed the effective date of ASC 820 for all non-financial assets and non-financial liabilities, except for items that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually), until the beginning of the first quarter of fiscal 2009. These include goodwill and other non-amortizable intangible assets. The adoption of ASC 820-10-55 did not have a significant impact on the Company’s operating results, financial position or cash flows. See Note Q “Asset Retirement Obligation” for more details.
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In June 2008, the FASB issued Emerging Issues Task Force (EITF) 03-6-1, Determining Whether Instruments Granted in Share-Based Payment Transactions Are Participating Securities (ASC 260). ASC 260 clarifies that share-based payment awards that entitle their holders to receive non-forfeitable dividends or dividend equivalents before vesting should be considered participating securities. The adoption of ASC 260 on January 1, 2009 did not have a significant impact on the Company’s operating results, financial position or cash flows.
NOTE C – SHORT TERM NOTES RECEIVABLE – RELATED PARTY
In July 2006, the Company made an unsecured $1.4 million loan to Eurenergy Resources Corporation (“Eurenergy”), a related party. The loan had an annual interest rate of 8% with principal and interest payable within 30 days after demand, and if not sooner demanded, on July 17, 2007. Effective July 17, 2007 the existing accrued interest was added to the principal balance, which increased the principal balance to $1,487,160, and the maturity date was extended to July 17, 2009. All other terms of the note remained the same. At May 21, 2009, the balance due including accrued interest totaled $1,798,456.
In June of 2008, the Company entered into a letter of credit agreement with Eurenergy. The terms of the agreement call for interest at the prime rate plus two percent. At May 21, 2009, the balance of the note and accrued interest was $2,172,441.
On November 20, 2007, the Company made a $630,000 loan to Prime Income Asset Management, Inc. (“PIAMI”). In 2008, the Company made additional net advances on the loan totaling approximately $6.3 million. The initial loan and the additional advances have been combined into a new loan with interest at the prime rate plus two percent.
On May 21, 2009, PIAMI acquired both Eurenergy notes receivable at face value plus accrued interest totaling $3,970,897.
Effective May 21, 2009 the Company and PIAMI entered into a new note combing all of the above loans into one note. The loan calls for interest at the prime rate plus 2% with principal and interest payable within 30 days after demand, and if not sooner demanded, on January 31, 2013.
At December 31, 2009, the balance due including accrued interest on the note receivable from PIAMI was $11.1 million.
In November 2007, the Company entered into an agreement with Eurenergy to provide accounting and administrative services at $15,000 per month. As of December 31, 2009, Eurenergy owes the Company $156,900 for such services. In June 2009, the agreement with Eurenergy expired. As of December 31, 2009, the amount receivable from Eurenergy has been fully reserved. The Company entered into a similar agreement with Energy Advisors, LLC in July 2009. As of December 31, 2009, Energy Advisors owes the Company $90,000 for accounting and administrative services.
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NOTE D – FAIR VALUE OF FINANCIAL INSTRUMENTS
The following methods and assumptions were used to estimate the fair value of each class of financial instruments for which it is practicable to estimate values at December 31, 2009 and 2007:
Cash and cash equivalents - The carrying amount approximates fair value because of the short maturity of these instruments.
Long-term debt - The fair value of the Company’s long-term debt is estimated based on market rates for the same or similar issues. The carrying value of long-term debt approximates its fair value.
Notes receivable – The fair value of the note receivable from an affiliate partnership is estimated to approximate fair value based on its short maturity. It is not practical to estimate the fair value of notes receivable from sale of properties because no quoted market exists and there are no comparable debt instruments to provide a basis for valuation.
NOTE E – NOTES PAYABLE
LONG TERM DEBT

Long-term debt is comprised of the following (in thousands):

|  |  | 2009 |  |  | 2008 |
| Notes payable from the acquisition of Mountaineer State Energy, Inc. |  | $ | 1,198 |  |  | $ | 1,026 |
| Asset retirement obligation |  |  | 2,450 |  |  |  | 2,334 |
| Other long-term liabilities |  |  | 326 |  |  |  | 394 |
|  |  | $ | 3,974 |  |  | $ | 3,754 |

Aggregate annual principal maturities of long-term debt at December 31, 2009 are as follows (in thousands):

2009 |  | $ | — |
2010 |  |  | — |
2011 |  |  | — |
2012 |  |  | — |
2013 |  |  | — |
Thereafter |  |  | 3,974 |
|  | $ | 3,974 |

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NOTE F – OPERATING LEASES
The Company leases a retirement community under an operating lease in which the basic term expires December 31, 2011, with options to renew for two consecutive five-year periods. The Company also has operating leases for equipment and office space. The leases generally provide that the Company pay property taxes, insurance and maintenance.
Future minimum payments following December 31, 2009 are as follows (in thousands):

2010 |  | $ | 965 |
2011 |  |  | 983 |
|  | $ | 1,948 |

Lease expense in 2009, 2008 and 2007 was $958,000, $954,000 and $845,000, respectively.
NOTE G - EARNINGS PER SHARE
The following table sets forth the computations of basic and diluted earnings per share (in thousands, except per share data):

|  | Year ended December 31, |
|  | 2009 |  |  | 2008 |  |  | 2007 |
Basic Earnings Per Share: |  |  |  |  |  |  |  |  |
Numerator: |  |  |  |  |  |  |  |  |
Net income from continuing operations |  | $ | (2,210 | ) |  | $ | 14,444 |  |  | $ | 689 |
Net (loss) from discontinued operations |  |  | — |  |  |  | — |  |  |  | (627 | )
Denominator: |  |  |  |  |  |  |  |  |  |  |  |
Weighted average shares outstanding |  |  | 1,737 |  |  |  | 1,737 |  |  |  | 987 |
Basic earnings per share from continuing operations |  |  | (1.27 | ) |  |  | 8.32 |  |  | $ | 0.70 |
Basic earnings per share from discontinued operations |  | $ | — |  |  | $ | — |  |  |  | (0.64 | )

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NOTE H – INCOME TAXES
At December 31, 2009, the Company had net operating loss carry forwards of approximately $6.8 million, which expire between 2012 and 2024.

Tax computed at the federal statutory rate of 34% (in thousands): |
|  | Year ended
|  | December 31,
|  | 2009 |  | 2008
Federal income tax expense (benefit) at the statutory rate |  | $ | (751 | ) | $ | 5,987
Utilization of net operating loss carryforwards |  |  | — |  |  | (5,406
Change in deferred tax asset valuation allowance |  |  |  |  |  |  |
attributable to continuing operations |  |  | 751 |  |  | (250
Federal income tax expense |  | $ | — |  | $ | 331

NOTE I – STOCKHOLDERS’ EQUITY

Outstanding Preferred Stock |  |  |
Preferred stock consists of the following (amounts in thousands): |  |  |
| Year Ended
| December 31,
| 2009 |  | 2008
Series B convertible preferred stock, $10 par value, liquidation value of $100, authorized 100 shares, issued and outstanding one share | 1 |  | 1

The Series B preferred stock has a liquidation value of $100 per share and is convertible into common stock over a ten-year period at prices escalating from $500 per share in 1993 to $1,111 per share by 2002. The right to convert expired April 30, 2003. Dividends at a rate of 6% are payable in cash or preferred shares at the option of the Company.
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NOTE J – GAIN (LOSS) ON SALE OF ASSETS
Acquisition and Sale of Leases for Mineral Interests
On November 21, 2007, a wholly owned subsidiary of New Concept entered into an agreement with Source Rock Energy of Arkansas, LLC, a Nevada limited liability company (“SRA”), a related party, to acquire 1,712 net acres of mineral leasehold interests in four separate sections of land in the Fayetteville Shale area of Arkansas in exchange for the issuance of a promissory note. Through such arrangement, the subsidiary also acquired two separate options to acquire additional leasehold acreage through August 15, 2008. The Company and its subsidiary intend to, subject to the availability of funds, develop such acreage through drilling of one or more exploratory wells on the property acquired. The acquisition price was $4,000 per net acre payable on December 31, 2010 with interest at 9.5% per annum. The two separate options to acquire additional acreage cover leasehold interests on 1,815 net acres and 583 net acres in the same county in Arkansas at the same price of $4,000 per net acre. On May 6, 2008, the Company exercised its options to acquire the additional acreage. Immediately subsequent to the exercise of the options, the Company sold the leasehold interest to an independent third party purchaser for $8,000 per acre. The Company recorded a gain of $16.4 million in the second quarter of 2008 as a result of the sale.
Disposition of Gainesville Outlet Mall
Effective December 31, 2007, the Company transferred all its ownership in the Gainesville Outlet Mall and approximately 40 acres of undeveloped land. The mall, which the Company acquired in 2003, has incurred both cash and accounting losses for the past several years. The Company recorded an impairment loss of $314,000 in the quarter ended March 31, 2007. Subsequent to March 31, 2007, the Company did not fund any cash shortfalls incurred by the mall.
Other Disposition
The Company leases and operates the Pacific Pointe Retirement Inn in King City, Oregon. On November 16, 2007 the Company sold, to an unrelated party, a portion of its future cash flow from its Retirement Center in Oregon for a cash payment of $750,000. More specifically the Company sold 25% of the cash flow for the 60 month period ending November 2012. For the period December 2012 through December 2022 the buyer will receive 10% of the cash flow from the retirement center.
NOTE K – OTHER INCOME (EXPENSE)
Other income (expense) consists of the following: (amounts in thousands)

|  |  | Year ended December 31, |
|  | 2009 |  |  | 2008 |  |  | 2007 |
Recovery of previously written off note receivable |  | $ | — |  |  | $ | 274 |  |  | $ | — |
Other |  |  | 68 |  |  |  | 190 |  |  |  | 142 |
|  | $ | 68 |  |  | $ | 464 |  |  | $ | 142 |

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NOTE L – DISCONTINUED OPERATIONS AND SALES OF REAL ESTATE
During 2007, the Company transferred ownership of the Gainesville Outlet Mall to an unrelated third party. During 2007, the Company incurred operating expenses related to the mall of approximately $101,000 as well as a loss on sale of assets of approximately $526,000. These losses have been reflected as discontinued operations in 2007.
NOTE M – CONTINGENCIES
Chesapeake Exploration Limited Partnership and Chesapeake Operating, Inc. (“Chesapeake”)
In January 2006, the Company entered into a joint operating agreement evidencing its acquisition of a 5% interest in two gas wells being drilled and ultimately operated by Chesapeake. The Company relied on the cost projections provided by Chesapeake to make its investment decision. Subsequent to its investment the Company received an invoice from Chesapeake for $556,217 which, according to Chesapeake, represents the Company’s 5% share of additional costs incurred by Chesapeake in drilling the wells. The Company believes that these additional costs far exceed any reasonable expense that should have been incurred in drilling the two wells and were incurred without notifying the Company of such expenses. The Company has requested an accounting of the additional expenses and a reconciliation of the final costs to the cost estimates previously presented. In April 2007, Chesapeake filed a lawsuit against the Company and others in State District Court in Tarrant County, Texas.
Other
The Company has been named as a defendant in other lawsuits in the ordinary course of business. Management is of the opinion that these lawsuits will not have a material effect on the financial condition, results of operations or cash flows of the Company.
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NOTE N – OPERATING SEGMENTS
The following table reconciles the segment information to the corresponding amounts in the Consolidated Statements of Operations and total assets:

|  | Oil and Gas |  |  | Retirement |  |  |  |  |  |  |
2009 |  | Operations |  |  | Facility |  |  | Corporate |  |  | Total |
Operating revenue |  | $ | 1,241 |  |  | $ | 2,857 |  |  | $ | — |  |  | $ | 4,098 |
Operating expenses |  |  | 1,340 |  |  |  | 2,270 |  |  |  | 1,023 |  |  |  | 4,633 |
Depreciation and amortization |  |  | 27 |  |  |  | 57 |  |  |  | — |  |  |  | 84 |
Depletion |  |  | 298 |  |  |  | — |  |  |  | — |  |  |  | 298 |
Accretion of asset retirement obligation |  |  | 117 |  |  |  | — |  |  |  | — |  |  |  | 117 |
Impairment of oil and gas properties |  |  | 1,695 |  |  |  | — |  |  |  | — |  |  |  | 1,695 |
Total operating expenses |  |  | 3,477 |  |  |  | 2,327 |  |  |  | 1,023 |  |  |  | 6,827 |
Interest expense |  |  | (123 | ) |  |  | — |  |  |  | — |  |  |  | (123 | )
Other income |  |  | 30 |  |  |  | — |  |  |  | 38 |  |  |  | 68 |
Interest income |  |  | — |  |  |  | — |  |  |  | 574 |  |  |  | 574 |
Segment operating income |  | $ | (2,329 | ) |  | $ | 530 |  |  | $ | (411 | ) |  | $ | (2,210 | )
Assets |  | $ | 13,103 |  |  | $ | 12,108 |  |  | $ | — |  |  | $ | 25,121 |

|  | Oil and Gas |  |  | Retirement |  |  |  |  |  |  |
2008 |  | Operations |  |  | Facility |  |  | Corporate |  |  | Total |
Operating revenue |  | $ | 672 |  |  | $ | 2,888 |  |  | $ | — |  |  | $ | 3,560 |
Operating expenses |  |  | 380 |  |  |  | 2,150 |  |  |  | 1,001 |  |  |  | 3,531 |
Depreciation and amortization |  |  | 4 |  |  |  | 55 |  |  |  | — |  |  |  | 59 |
Depletion |  |  | 112 |  |  |  | — |  |  |  | — |  |  |  | 112 |
Total operating expenses |  |  | 496 |  |  |  | 2,205 |  |  |  | 1,001 |  |  |  | 3,702 |
Interest expense |  |  | (40 | ) |  |  | — |  |  |  | (230 | ) |  |  | (270 | )
Other income |  |  | — |  |  |  | — |  |  |  | 464 |  |  |  | 464 |
Interest income |  |  | — |  |  |  | — |  |  |  | 785 |  |  |  | 785 |
Gain on land sales |  |  | 16,432 |  |  |  | — |  |  |  | — |  |  |  | 16,432 |
Segment operating income |  | $ | 16,568 |  |  | $ | 683 |  |  | $ | 18 |  |  | $ | 17,269 |
Assets |  | $ | 12,158 |  |  | $ | 11,900 |  |  | $ | — |  |  | $ | 24,058 |
Property Sales |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Sales price |  | $ | 32,868 |  |  | $ | — |  |  | $ | — |  |  | $ | 32,868 |
Cost of sale |  |  | 16,432 |  |  |  | — |  |  |  | — |  |  |  | 16,432 |
Gain on sale |  | $ | 16,432 |  |  | $ | — |  |  | $ | — |  |  | $ | 32,868 |

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NOTE O - QUARTERLY DATA (UNAUDITED)
The table below reflects the Company’s selected quarterly information for the years ended December 31, 2009 and 2008. Amounts shown are in thousands except per share amounts.

|  | First |  |  | Second |  |  | Third |  |  | Fourth |
Year ended December 31, 2009 |  | Quarter |  |  | Quarter |  |  | Quarter |  |  | Quarter |
Revenue |  | $ | 1,068 |  |  | $ | 1,049 |  |  | $ | 970 |  |  | $ | 1,011 |
Operating (expense) |  |  | (965 | ) |  |  | (992 | ) |  |  | (864 | ) |  |  | (1,288 | )
Corporate general and administrative expense |  |  | (262 | ) |  |  | (235 | ) |  |  | (169 | ) |  |  | (357 | )
Impairment of natural gas and oil properties |  |  | — |  |  |  | — |  |  |  | — |  |  |  | (1,695 | )
Other income (expense) net |  |  | 182 |  |  |  | 94 |  |  |  | 112 |  |  |  | 131 |
Provision for income taxes |  |  | — |  |  |  | — |  |  |  | — |  |  |  | — |
Gain on sale of mineral rights |  |  | — |  |  |  | — |  |  |  | — |  |  |  | — |
Net income (loss) from continuing operations |  |  | 23 |  |  |  | (84 | ) |  |  | 49 |  |  |  | (2,198 | )
Income (loss) allocable to common shareholders |  |  | 23 |  |  |  | (84 | ) |  |  | 49 |  |  |  | (2,198 | )
Income (loss) per common share – basic |  | $ | 0.01 |  |  | $ | (.04 | ) |  | $ | 0.03 |  |  | $ | (1.27 | )

Year ended December 31, 2008 |  |  |  |  |  |  |  |  |  |  |  |
Revenue |  | $ | 704 |  |  | $ | 699 |  |  | $ | 858 |  |  | $ | 1,299 |
Operating (expense) |  |  | (551 | ) |  |  | (550 | ) |  |  | (652 | ) |  |  | (948 | )
Corporate general and administrative expense |  |  | (261 | ) |  |  | (264 | ) |  |  | (108 | ) |  |  | (368 | )
Impairment of natural gas and oil properties |  |  | — |  |  |  | — |  |  |  | — |  |  |  | — |
Other income (expense) net |  |  | 164 |  |  |  | 276 |  |  |  | 524 |  |  |  | 15 |
Provision for income taxes |  |  | — |  |  |  | (1,626 | ) |  |  | — |  |  |  | (148 | )
Net income (loss) from continuing operations |  |  | — |  |  |  | 16,432 |  |  |  | — |  |  |  | — |
Gain (loss) from discontinued operations |  |  | 56 |  |  |  | 14,967 |  |  |  | 622 |  |  |  | (150 | )
Income (loss) allocable to common shareholders |  |  | 56 |  |  |  | 14,967 |  |  |  | 622 |  |  |  | (150 | )
Income (loss) per common share – basic and diluted |  | $ | 0.04 |  |  | $ | 7.73 |  |  | $ | 0.25 |  |  | $ | (0.08 | )

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NOTE P - SUPPLEMENTARY FINANCIAL INFORMATION ON OIL AND NATURAL GAS EXPLORATION, DEVELOPMENT AND PRODUCTION ACTIVITIES (UNAUDITED)
The Company’s net ownership interests in estimated quantities of proved oil and natural gas reserves and changes in net proved reserves, all of which are located in the continental United States, are summarized below:

|  | 2009 |
|  | Gas (MMCF) |  |  | Oil (MBBLS) |
Proved developed and undeveloped reserves — |  |  |  |  |  |
January 1, 2009 |  |  | 7,397 |  |  |  | 37 |
Purchase of oil and natural gas properties in place |  |  | - |  |  |  | - |
Discoveries and extensions |  |  | - |  |  |  | - |
Revisions |  |  | 400 |  |  |  | (14 | )
Sales of oil and gas properties in place |  |  |  |  |  |  | - |
Production |  |  | (236 | ) |  |  | (4 | )
End of year |  |  | 7,561 |  |  |  | 19 |
Proved developed reserves at beginning of year |  |  | 2,703 |  |  |  | 37 |
Proved developed reserves at end of year |  |  | 2,867 |  |  |  | 19 |
|  | 2008 |
|  | Gas (MMCF) |  |  | Oil (MBBLS) |
Proved developed and undeveloped reserves — |  |  |  |  |  |  |  |
September 15, 2008 (pre-acquisition) |  |  | - |  |  |  | - |
Purchase of oil and natural gas properties in place |  |  | 6,080 |  |  |  | 44 |
Discoveries and extensions |  |  | - |  |  |  | - |
Revisions |  |  | - |  |  |  | - |
Sales of oil and gas properties in place |  |  | - |  |  |  | - |
Production |  |  | (83 | ) |  |  | (7 | )
End of year |  |  | 7,397 |  |  |  | 37 |
Proved developed reserves at acquisition |  |  | 2,786 |  |  |  | 44 |
Proved developed reserves at end of year |  |  | 2,703 |  |  |  | 37 |

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The following table presents the changes in our total proved undeveloped reserves.

|  | Gas |  |  | Oil |
|  | (MMCF) |  |  | (MBBLS) |
Proved undeveloped reserves as of December 31, 2007 |  |  | - |  |  |  | - |
Purchase of reserves |  |  | 4,694 |  |  |  | - |
Conversion to proved developed reserves |  |  | - |  |  |  | - |
Proved undeveloped reserves as of December 31, 2008 |  |  | 4,694 |  |  |  | - |
Conversion to proved developed reserves |  |  | - |  |  |  | - |
Proved undeveloped reserves as of December 31, 2009 |  |  | 4,694 |  |  |  | - |

The following table reflects the capitalized costs relating to oil and gas producing activities.

|  | 2009 |  |  | 2008 |
Property acquisition costs: |  |  |  |  |  |
Proved properties (2009 reflects an adjustment to the |  |  |  |  |  |
2008 acquisition costs) |  | $ | 11,782 |  |  | $ | 13,134 |
Unproved properties |  |  | - |  |  |  | - |
Accumulated depreciation, depletion and amortization |  |  |  |  |  |  |  |
and valuation allowance |  |  | (410 | ) |  |  | (112 | )
Net capitalized costs |  | $ | 11,372 |  |  | $ | 13,022 |

The following table reflects the costs incurred in oil and gas property acquisition, exploration and development activities.

|  | 2009 |  |  | 2008 |
Property acquisition costs: |  |  |  |  |  |
Proved properties |  | $ | - |  |  | $ | 13,134 |
Unproved properties |  |  | - |  |  |  | - |
Exploration costs |  |  | - |  |  |  | - |
Development costs |  |  | - |  |  |  | - |
Total cost incurred |  | $ | - |  |  | $ | 13,134 |

The following table reflects revenues and expenses directly associated with our oil and gas producing activities, including general and administrative expenses directly related to such producing activities. They do not include any allocation of interest costs or general corporate overhead and, therefore, are not necessarily indicative of the contribution to net earnings of our oil and gas operations. Income tax expense has been calculated by applying statutory income tax rates to oil and gas sales after deducting costs, including depreciation, depletion and amortization and after giving effect to permanent differences.
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|  | 2009 |  |  | 2008 |
Oil and gas sales |  | $ | 1,241 |  |  | $ | 672 |
Production expenses |  |  | (1,190 | ) |  |  | (370 | )
Exploration expenses |  |  | - |  |  |  | - |
Taxes other than income taxes |  |  | (10 | ) |  |  | (10 | )
Depreciation, depletion and amortization |  |  | (442 | ) |  |  | (116 | )
Impairment of oil and gas properties |  |  | (1,695 | ) |  |  | - |
General and administrative expenses |  |  | (140 | ) |  |  | (40 | )
Income tax benefit (expense) |  |  | - |  |  |  | - |
Results of operations |  | $ | (2,236 | ) |  | $ | 136 |

The following table reflects the standardized measure of future net cash flows related to our proved reserves.

|  | 2009 |  |  | 2008 |
Future oil and gas cash inflows |  | $ | 49,250 |  |  | $ | 66,539 |
Future oil and gas operating expenses |  |  | (9,318 | ) |  |  | (14,599 | )
Future development costs |  |  | (13,589 | ) |  |  | (15,368 | )
Future income tax expense |  |  | (184 | ) |  |  | (419 | )
Future net cash flows |  |  | 26,159 |  |  |  | 36,153 |
10% discount to reflect timing of cash flows |  |  | (14,372 | ) |  |  | (18,705 | )
Standardized measure of discounted future net cash flows |  | $ | 11,372 |  |  | $ | 17,808 |

The following table reflects the principal changes in the standardized measure of discounted future net cash flows attributable to our proved reserves.

|  | 2009 |  |  | 2008 |
Beginning balance |  | $ | 17,808 |  |  | $ | - |
Oil and gas sales, net of production costs |  |  | (51 | ) |  |  | - |
Purchase of reserves, net of future development costs |  |  | - |  |  |  | 17,808 |
Net changes in prices and production costs |  |  | (6,385 | ) |  |  | - |
Extensions and discoveries, net of future development costs |  |  | - |  |  |  | - |
Revisions of quantity estimates |  |  | - |  |  |  | - |
Other changes |  |  | - |  |  |  | - |
Ending balance |  | $ | 11,372 |  |  | $ | 17,808 |

NOTE Q – ASSET RETIREMENT OBLIGATION
The Company records an asset retirement obligation (ARO) when the total depth of a drilled well is reached and the Company can reasonably estimate the fair value of an obligation to perform site reclamation, dismantle facilities or plug and abandon costs. The Company records the ARO liability on the consolidated balance sheets and capitalizes a portion of the cost in “Oil and natural gas properties” during the period in which the obligation is incurred. In general, the amount of an ARO and the costs capitalized will be equal to the estimated future cost to satisfy the abandonment obligation using current prices that are escalated by an assumed inflation factor up to the estimated settlement date and adjusted for the Company’s credit risk. This amount is then discounted back to the date that the abandonment obligation was incurred using an assumed cost of funds for the Company. After recording these amounts, the ARO is accreted to its future estimated value using the same assumed cost of funds. The additional capitalized costs are depreciated on a unit-of-production basis or straight-line basis.
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(in thousands) |  | 2009 |  |  | 2008 |
Asset retirement obligation, January 1 |  | $ | 2,334 |  |  | $ | - |
Acquisition of oil and gas properties |  |  | - |  |  |  | 2,334 |
Revisions in the estimated cash flows |  |  | - |  |  |  | - |
Liability incurred upon acquiring and drilling wells |  |  | - |  |  |  | - |
Liability settled upon plugging and abandoning wells |  |  | - |  |  |  | - |
Accretion of discount expense |  |  | 116 |  |  |  | - |
Asset retirement obligation, December 31 |  | $ | 2,450 |  |  | $ | 2,334 |

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