10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTER ENDED SEPTEMBER 30, 2013

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)		(I.R.S. Employer Identification No.)
1603 LBJ Freeway Suite 300 Dallas, Texas
	(Address of principal executive offices)
	75234
	(Zip Code)
	(972) 407-8400
	(Registrant’s telephone number, including area code)

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: RNo: £

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes: R   No £

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

	Large accelerated filer £	Accelerated filer £
	Non-accelerated filer £	Smaller reporting company R
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).			Yes: £No: R

Indicate the number of shares outstanding of each of the issuer’s classes of Common Stock, as of the latest practicable date.

Common Stock, $.01 par value	1,946,935 shares
(Class)	(Outstanding at November 6, 2013)

1

NEW CONCEPT ENERGY, INC. AND SUBSIDIARIES

Index to Quarterly Report on Form 10-Q

Period ended September 30, 2013

PART I:  FINANCIAL INFORMATION
Item 1.  Financial Statements	3
Consolidated Balance Sheets	3
Consolidated Statements of Operations	5
Consolidated Statements of Cash Flows	6
Notes To Consolidated Financial Statements	7
Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations	11
Item 3.  Quantitative and Qualitative Disclosures About Market Risk	14
Item 4.  Controls and Procedures	14
PART II:  OTHER INFORMATION	15
Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds	15
Item 6.  Exhibits	16
Signatures	17

2

PART I.  FINANCIAL INFORMATION

Item 1.  Financial Statements

NEW CONCEPT ENERGY, INC. AND SUBSIDARIES
CONSOLIDATED BALANCE SHEETS
(unaudited)
(amounts in thousands)
	September 30, 2013		December 31,  2012
Assets
Current assets
Cash and cash equivalents	$	1,276	$	398
Accounts receivable from oil and gas sales		233		210
Other current assets		7		2
Total current assets		1,516		610
Oil and natural gas properties (full cost accounting method)
Proved developed and undeveloped oil and gas properties, net of depletion		9,294		9,717
Property and equipment, net of depreciation
Land, buildings and equipment - oil and gas operations		1,461		1,410
Other		193		204
Total property and equipment		1,654		1,614
Other assets (including $120,750 and $161,300 due from related parties
in 2013 and 2012		590		543
Total assets	$	13,054	$	12,484

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

3

NEW CONCEPT ENERGY, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS - CONTINUED
(unaudited)
(amounts in thousands, except share amounts)
	September 30, 2013			December 31, 2012
Liabilities and stockholders' equity
Current liabilities
Accounts payable - trade	$	119		$	38
Accrued expenses		289			173
Current portion of long term debt		53			93
Total current liabilities		461			304
Long-term debt
Notes payable less current portion		2,334			2,273
Asset retirement obligation		2,770			2,770
Other long-term liabilities		541			491
Total liabilities		6,106			5,838
Stockholders' equity
Preferred stock, Series B		1			1
Common stock, $.01 par value; authorized, 100,000,000
shares; issued and outstanding, 1,946,935 shares
at June 30, 2013 and December 31, 2012		20			20
Additional paid-in capital		58,838			58,838
Accumulated deficit		(51,911	)		(52,213	)
		6,948			6,646
Total liabilities & equity	$	13,054		$	12,484

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

4

NEW CONCEPT ENERGY, INC AND SUBSIDIARIES
CONSOLIDATED STATEMENT OF OPERATIONS
(unaudited)
(amounts in thousands, except per share data)
	For the Three Months  ended September 30,						For the Nine Months ended September 30,
	2013			2012			2013			2012
Revenue
Oil and gas operations, net of royalties	$	324		$	274		$	1,048		$	889
Real estate operations		694			702			2,040			2,039
		1,018			976			3,088			2,928
Operating expenses
Oil and gas operations		495			432			1,444			1,356
Real estate operations		372			359			1,141			1,078
Lease expense		235			231			707			693
Corporate general and administrative		170			108			513			402
Accretion of asset retirement obligation		-			-			-			68
Impairment of natural gas and oil properties		-			-			-			912
		1,272			1,130			3,805			4,509
Operating earnings (loss)		(254	)		(154	)		(717	)		(1,581	)
Other income (expense)
Interest income		1			-			9			-
Interest expense		(24	)		(52	)		(97	)		(170	)
Recovery of bad debt expense		410			1,726			1,143			1,700
Other income (expense), net		-			-			(36	)		135
Other income (expense)		387			1,674			1,019			1,665
	$	133		$	1,520		$	302		$	84
Net income (loss) applicable to common shares
	$	0.07		$	0.78		$	0.16		$	0.04
Net income (loss) per common share-basic and diluted
Weighted average common and equivalent shares outstanding - basic		1,947			1,947			1,947			1,947

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

5

NEW CONCEPT ENERGY, INC AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(unaudited)
(amounts in thousands)
	For the Nine Months Ended
	September 30,
	2013			2012
Cash flows from operating activities
Net income	$	302		$	84
Adjustments to reconcile net income to net cash provided by (used in) operating activities
Depreciation, depletion and amortization		687			570
Accretion of asset retirement obligation		-			158
Write-off (recovery) of affiliate receivable		(1,143	)		(1,700	)
Changes in operating assets and liabilities
Other current and non-current assets		(110	)		(277	)
Accounts payable and other liabilities		1,341			521
Impairment of oil and gas properties		-			912
Net cash provided by (used) in operating activities		1,077			268
Cash flows from investing activities
Investment in oil and gas		(82	)		(79	)
Fixed asset additions		(150	)		(71	)
Net cash provided by (used in) investing activities		(232	)		(150	)
Cash flows from financing activities
Proceeds from loans		62			42
Payment on notes payable		(29	)		(34	)
Net cash provided by (used in) financing activities		33			8
Net increase (decrease) in cash and cash equivalents		878			126
Cash and cash equivalents at beginning of year		398			109
Cash and cash equivalents at end of year	$	1,276		$	235

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

6

NEW CONCEPT ENERGY, INC. AND SUBSIDIARIES

Notes To Consolidated Financial Statements

NOTE A: BASIS OF PRESENTATION

The accompanying unaudited consolidated financial statements include the accounts of New Concept Energy, Inc. and its majority-owned subsidiaries (collectively, “NCE” or the “Company”).  All significant intercompany transactions and accounts have been eliminated.  

The unaudited financial statements included herein have been prepared by the Company without audit, pursuant to the rules and regulations of the Securities and Exchange Commission.  The financial statements reflect all adjustments that are, in the opinion of management, necessary to fairly present such information.  All such adjustments are of a normal recurring nature.  Although the Company believes that the disclosures are adequate to make the information presented not misleading, certain information and footnote disclosures, including a description of significant accounting policies normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America, have been condensed or omitted pursuant to such rules and regulations.

These financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ending December 31, 2012.  Operating results for the nine month period ended September 30, 2013 are not necessarily indicative of the results that may be expected for any subsequent quarter or for the fiscal year ending December 31, 2013.

NOTE B: NATURE OF OPERATIONS

The Company 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.

The Company also leases and operates a retirement community in King City Oregon, with a capacity of 114 residents.

NOTE C: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

We consider accounting policies related to our estimates of depreciation amortization and depletion, segments, oil and gas properties, oil and gas reserves, gas gathering assets, office and field equipment, revenue recognition and gas imbalances, leases, revenue recognition for real estate operations, impairment, and sales of real estate as significant accounting policies.  The policies include significant estimates made by management using information available at the time the estimates are made.  However, these estimates could change materially if different information or assumptions were used.  These policies are summarized in our Annual Report on Form 10-K for the year ended December 31, 2012.

NOTE D: OIL AND GAS RESERVES

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.

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 a standardized method for determining pricing and require that future cash flow be discounted using a 10% rate. The valuation that results may not represent management’s estimated current market value of proved reserves.

7

During the past few years the exploration, development and production of natural gas has resulted in an oversupply of natural gas which has resulted in a substantial reduction in the market price. Management of the Company believes that this oversupply will last for some time and does not anticipate an increase in the price we can receive in the market place. In April 2012 the Company entering into an agreement to fix the price it receives for the sale of its gas. For the five years ended April 2017 the Company will receive $4.53 per MCF. While the lock-in price is higher than the current market price for natural gas when applying the new price using the formula mandated by the accounting rules the result was a reduction of $912,000 in value of the Company’s recorded interests in its oil and gas properties. This reduction in value was reflected in financial statements of the company as of March 2012.

NOTE E – RECEIVABLE FROM PRIME INCOME ASSET MANAGEMENT

Prime Income Asset Management, Inc (“PIAMI”), a related party, is a real estate management company that also invests in real estate for its own account. PIAMI is indirectly owned by a private trust. URC Energy, Inc is and has been a significant investor in the Company. URC Energy, Inc is indirectly owned by a private trust. While the two trusts are separate they have similar trustees and beneficiaries and therefore the Company has noted PIAMI as a related party.

Beginning in 2006 the Company made loans to certain related parties at interest rates higher than the Company believes it could have gotten elsewhere. For a more complete discussion of history of the receivable, the establishment of a reserve due to concerns regarding collectability if the receivable and the recovery efforts refer to the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, in Item 13 on page 26 and Footnote C on page 45.

In the fourth quarter of 2011 the Company determined that the financial condition of PIAMI had deteriorated and there could be no assurance that the amount owed would or could be collected. In 2011, the Company recorded a reserve of $10 million and fully reserved the receivable. Any future collections of the receivable will be reflected as income in the period in which it is collected.

Beginning in 2011 the Company conducted business with Pillar Income Asset Management (“Pillar”), a related party, whereby Pillar would provide the Company with services including processing Payroll, acquiring insurance etc. The Company believes that by purchasing these services through certain large entities it can get lower costs and better service. Pillar has not charged the Company a fee for providing these services.

While separate companies both PIAMI and Pillar are both owned by Realty Advisors, Inc. (“RAI”).  During 2011 and 2012 the Company incurred obligations to Pillar totaling approximately $1.7 million. In a joint agreement among Pillar, PIAMI, RAI and the Company, Pillar agreed to relieve the Company of its obligation to pay $1.7 million and the Company agreed to reduce the amount owed by Prime by a like amount. In the third quarter of 2012 the Company recorded a $1.7 million gain on the transaction. In the fourth quarter of 2012 Pillar incurred expenses on behalf of the Company of $376,000 and agreed to forego payment in exchange for a reduction in the PIAMI obligation. The Company recorded an additional $376,000 gain.

For the nine months ended September 30, 2013 Pillar incurred expenses on behalf of the Company of $1,143,000 and agreed to forego payment in exchange for a reduction in PIAMI obligation. The Company recorded an additional $1,143,000 gain.

NOTE F: CONTINGENCIES

Carlton Energy Group, LLC

In December 2006, Carlton Energy Group, LLC (“Carlton”) instituted litigation against an individual, EurEnergy Resources Corporation (“EurEnergy”) and several other entities including New Concept Energy, Inc., which was then known as CabelTel International Corporation (the “Company”) alleging tortuous conduct, breach of contract and other matters and as to the Company that it was the alter ego of EurEnergy. The Carlton claims were based upon an alleged tortuous interference with a contract by the individual and EurEnergy related to the right to explore a coal bed methane concession in Bulgaria which had never (and has not to this day) produced any hydrocarbons. At no time during the pendency of this project or since did the company or any of its officers or directors have any interest whatsoever in the success or failure of the so-called “Bulgaria Project”. However, in the litigation, Carlton alleged that the Company was the alter-ego of certain of the other Defendants including EurEnergy.

Following a jury trial in 2009, the Trial Court (295th District Court of Harris County, Texas) reduced the actual damages found by the jury of $66.5 million and entered judgment against EurEnergy and The individual jointly and severally for $31.16 million in actual damages on its tortuous-interference claim and the Court further assessed exemplary damages against The individual and EurEnergy in the amount of $8.5 million each. The Court granted a judgment for the Company that it was not the alter ego of any of the other parties and thereby would not incur any damages.

Cross appeals were filed by Carlton, the individual and EurEnergy to the Court of Appeals for the First District of Texas (the “Court of Appeals”) which rendered its opinion on February 14, 2012.  The Court of Appeals opinion, among other things, reinstated the jury award of actual damages jointly and severely against the individual and EurEnergy in the amount of $66.5 million and overturned the Trial Court’s ruling favorable to the Company rendering a judgment for that amount plus exemplary damages against the Company as the “alter ego” of EurEnergy.

8

The Company, and the other defendants, filed a Petition for Review of the Court of Appeals Opinion with the Supreme Court of the State of Texas. After requesting a response from the Plaintiff the Supreme Court requested full briefing on the merits. In March 2013 the Supreme Court granted the Petition for Review and the Supreme Court heard oral arguments on the matter in September 2013. The parties are awaiting the ruling by the Supreme Court.

The Company vigorously denies that it is the “alter ego” of any other entity; further the Company strongly believes that the Court of Appeals opinion is erroneous in concluding that the Company is an “alter ego” of any other entity which is contrary to Nevada substantive law. There are also questions regarding the underlying liability of EurEnergy and if EurEnergy is successful in its petition for review or, even if unsuccessful if the Company is successful on its positions described above, the Trial Court’s judgment could be reinstated and the Company would have no liability on this claim.

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.

In March 2011, Chesapeake received a summary judgment award including prejudgment interest for $686,874 plus $65,000 in legal fees. The judgment did however acknowledge that the plaintiff did not pay the company for it’s pro rata share of the gas produced by the two wells.

The Company appealed the judgment to the Court of Appeals which reduced the judgment by approximately $16,000 but otherwise affirmed the lower court ruling. The company filed an appeal with the Texas Supreme Court however on February 15, 2013 the Supreme Court denied the petition.

The Company is pursuing its legal remedies to offset the revenue for gas that has been previously produced and held by Chesapeake against the amount due Chesapeake. The Company has recorded a liability due Chesapeake which it believes is sufficient to provide for the net obligation to Chesapeake.

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. 

NOTE G:  OPERATING SEGMENTS

The following table reconciles the segment information to the corresponding amounts in the Consolidated Statements of Operations and total assets:

Three months ended September 30, 2013	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	324		$	694	$	-	$	1,018
Operating expenses		308			357		170		835
Depreciation, depletion and amortization		187			15		-		202
Lease expense		-			235		-		235
Total operating expenses		495			607		170		1,272
Interest income		-			-		1		1
Interest expense		(24	)		-		-		(24	)
Recovery of bad debt expense		-			-		410		410
Other income		-			-		-		-
Segment operating income	$	(195	)	$	87	$	241	$	133

9

Three months ended September 30, 2012	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	274		$	702	$	-	$	976
Operating expenses		264			341		108		713
Depreciation, depletion and amortization		168			18		-		186
Lease expense		-			231		-		231
Accretion of asset retirement obligation		-			-		-		-
Total operating expenses		432			590		108		1,130
Interest expense		(52	)		-		-		(52	)
Recovery of bad debt expense		-			-		1,700		1,700
Other income		-			-		26		26
Segment operating income	$	(210	)	$	112	$	1,618	$	1,520

Nine months ended September 30, 2013	Oil and Gas Operations			Retirement Facility		Corporate			Total
Operating revenue	$	1,048		$	2,040	$	-		$	3,088
Operating expenses		874			1,096		513			2,483
Depreciation, depletion and amortization		570			45		-			615
Lease expense		-			707		-			707
Total operating expenses		1,444			1,848		513			3,805
Interest income		-			-		9			9
Interest expense		(97	)		-		-			(97	)
Recovery of bad debt expense		-			-		1,143			1,143
Other income		-			-		(36	)		(36	)
Segment operating income	$	(493	)	$	192	$	603		$	302

Nine months ended September 30, 2012	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	889		$	2,039	$	-	$	2,928
Operating expenses		850			1,040		402		2,292
Depreciation, depletion and amortization		506			38		-		544
Lease expense		-			693		-		693
Accretion of asset retirement obligation		68			-		-		68
Impairment of natural gas and oil properties		912			-		-		912
Total operating expenses		2,336			1,771		402		4,509
Interest expense		(170	)		-		-		(170	)
Recovery of bad debt expense		-			-		1,700		1,700
Other income		-			-		135		135
Segment operating income	$	(1,617	)	$	268	$	1,433	$	84

10

NOTE H:  NEWLY ISSUED ACCOUNTING STANDARDS

We have considered all other newly issued accounting guidance that is applicable to our operations and the preparation of our consolidated statements, including that which we have not yet adopted.  We do not believe that any such guidance will have a material effect on our financial position or results or operation.

NOTE I:  SUBSEQUENT EVENTS

The Company has evaluated subsequent events through November 6, 2013, the date the financial statements were available to be issued, and has determined that there are none to be reported.

Item 2.  Management's Discussion and Analysis of Financial Condition and Results of Operations

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.

The Company’s significant accounting policies are summarized in Note B to our consolidated financial statements in our annual report on Form 10-K.  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.

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 a standardized method for determining pricing and require that future cash flow be discounted using a 10% rate. The valuation that results may not represent management’s estimated current market value of proved reserves.

Doubtful Accounts

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.

11

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 September 30, 2013, 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 September 30, 2013, the Company had current assets of $1,516,000 and current liabilities of $461,000.

Cash and cash equivalents at September 30, 2013 were $1,276,000 as compared to $398,000 at December 31, 2012.

Net cash used in operating activities was $1,077,000 for the nine months ended September 30, 2013.  During the nine-month period, the Company had net income of $302,000. Included in operating activities were non cash expenses including depreciation, depletion and amortization of $687,000.

Net cash used in investing activities was $232,000 for the nine months ended September 30, 2013, consisting of furnishings at the retirement facility and the purchase of equipment and other capitalized drilling costs at both the Company’s oil and gas production facility.

Net cash used in financing activities was $33,000 for the nine months ended September 30, 2013, consisting of a net increase in loans from a bank of $62,000 and repayment of bank loans of $29,000.

Results of Operations

The following discussion is based on our Consolidated Statements of Operations for the three and nine months ended September 30, 2013 and 2012 as included in Part 1, Item 1: Financial statements of this report.

Comparison of the three months ended September 30, 2013 to the same period ended 2012

The Company reported net income of $133,000 for the three months ended September 30, 2013, as compared to a net income of $1,520,000 for the similar period in 2012.

For the three months ended September 30, 2013, the Company recorded oil and gas revenues, net of royalty expenses of $324,000 as compared to $274,000 for the comparable period of 2012. The changes in oil and gas revenue was due to new oil wells that were drilled in late 2012.

The Company recorded revenues of $694,000 for the three months ended September 30, 2013 from its retirement property compared to $702,000 for the comparable period in 2012.

For the three months ended September 30, 2013, the Company recorded oil and gas operating expenses of $495,000 as compared to $432,000 for the comparable period of 2012. The increase was partially due to an increase in depletion expense of $19,000. The balance of the increases in operating expenses were due to an overall increase in expenses.

For the three months ended September 30, 2013, operating expenses at the retirement property were $372,000 as compared to $359,000 for the comparable period in 2012. The increases in operating expenses were due to an overall increase in non-payroll related expenses.

For the three months ended September 30, 2013, corporate general & administrative expenses were $170,000 as compared to $108,000 for the comparable periods in 2012. The increase is primarily due to legal fees incurred by the company to defend itself against certain lawsuits.

For the three months ended September 30, 2013, interest expense was $24,000 as compared to $52,000 for the comparable period in 2012. The reduction is due to a lower accrual of interest with respect to the long term obligations associated with the acquisition of our oil and gas subsidiary.

For the three months ended September 30, 2013 the company recorded a bad debt expense recovery of $410,000 with respect to a note receivable of approximately $10 million that was fully reserved in a prior (See footnote E).

12

Comparison of the nine months ended September 30, 2013 to the same period ended 2012

The Company reported net income of $302,000 for nine months ended September 30, 2013, as compared to net income of $84,000 for the similar period in 2012.

For the nine months ended September 30, 2013, the Company recorded oil and gas revenues of $1,048,000 as compared to $889,000 for the comparable period of 2012.  The changes in oil and gas revenue was due to new oil wells that were drilled in late 2012.

The Company recorded revenues of $2,040,000 for the nine months ended September 30, 2013 from its retirement property compared to $2,039,000 for the comparable period in 2012.  

For the nine months ended September 30, 2013, the Company recorded oil and gas operating expenses of $1,444,000 as compared to $1,356,000 for the comparable period of 2012.  The increase was principally due to an increase in depletion expense.

For the nine months ended September 30, 2013, operating expenses at the retirement property were $1,141,000 as compared to $1,078,000 for the comparable period in 2012. The increases in operating expenses were due to an overall increase in non-payroll related expenses.

For the nine months ended September 30, 2013, corporate general & administrative expenses were $513,000 as compared to $402,000 for the comparable periods in 2012.  The increase is primarily due to legal fees incurred by the company to defend itself against certain lawsuits.

For the nine months ended September 30, 2012 the Company recorded an expense for Impairment Natural Gas and Oil Properties of $912,000. In April 2012 the Company entering into an agreement to fix the price it receives for the sale of its gas. For the five years ended April 2017 the Company will receive $4.53 per MCF. While the lock-in price is higher than the current market price for natural gas when applying the new price using the formula mandated by the accounting rules the result was a reduction of $912,000 in value of the Company’s recorded interests in its oil and gas properties. This reduction in value was reflected in financial statements of the company as of March 2012.

 For the nine months ended September 30, 2013 the Company recorded interest expense of $97,000 as compared to $170,000 for the comparable periods in 2012. The reduction is due to a lower accrual of interest with respect to the long term obligations associated with the acquisition of our oil and gas subsidiary.

For the nine months ended September 30, 2013 the company recorded a bad debt expense recovery of $1,143,000 with respect to a note receivable of approximately $10 million that was fully reserved in a prior year ( See footnote E).

The Company recorded other expense of $36,000 for the nine months ended September 30, 2013 which is comprised of various miscellaneous items. For the nine months ended September 30, 2013 the Company recorded other income of $135,000 of which $104,000 was the result of a legal settlement where the Company had previously over accrued for its portion of the loss.

Forward Looking Statements

“Safe Harbor” Statement under the Private Securities Litigation Reform Act of 1995:  A number of the matters and subject areas discussed in this filing that are not historical or current facts deal with potential future circumstances, operations and prospects.  The discussion of such matters and subject areas is qualified by the inherent risks and uncertainties surrounding future expectations generally, and also may materially differ from the Company’s actual future experience involving any one or more of such matters and subject areas relating to interest rate fluctuations, the ability to obtain adequate debt and equity financing, demand, pricing, competition, construction, licensing, permitting, construction delays on new developments, contractual and licensure, and other delays on the disposition, transition, or restructuring of currently or previously owned, leased or managed properties in the Company’s portfolio, and the ability of the Company to continue managing its costs and cash flow while maintaining high occupancy rates and market rate charges in its retirement community.  The Company has attempted to identify, in context, certain of the factors that it currently believes may cause actual future experience and results to differ from the Company’s current expectations regarding the relevant matter of subject area.  These and other risks and uncertainties are detailed in the Company’s reports filed with the Securities and Exchange Commission (“SEC”), including the Company’s Annual Reports on Form 10-K and Quarterly Reports on Form 10-Q.

13

Inflation

The Company’s principal source of revenue is rents from a retirement community and fees for services rendered.  The real estate operation is affected by rental rates that are highly dependent upon market conditions and the competitive environment in the areas where the property is located.  Compensation to employees and maintenance are the principal cost elements relative to the operation of this property.  Although the Company has not historically experienced any adverse effects of inflation on salaries or other operating expenses, there can be no assurance that such trends will continue or that, should inflationary pressures arise, the Company will be able to offset such costs by increasing rental rates in its real estate operation.

Environmental Matters

The Company has conducted environmental assessments on most of its existing owned or leased properties.  These assessments have not revealed any environmental liability that the Company believes would have a material adverse affect on the Company’s business, assets or results of operations.  The Company is not aware of any such environmental liability.  The Company believes that all of its properties are in compliance in all material respects with all federal, state and local laws, ordinances and regulations regarding hazardous or toxic substances or petroleum products.  The Company has not been notified by any governmental authority and is not otherwise aware of any material non-compliance, liability or claim relating to hazardous or toxic substances or petroleum products in connection with any of its communities.

Item 3.  Quantitative and Qualitative Disclosures about Market Risk

Interest Rate Risk

Nearly 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 4.  CONTROLS AND PROCEDURES

(a)           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.

(b)           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.

14

PART II:  OTHER INFORMATION

Item 2.  Unregistered Sales of Equity Securities and Use of Proceeds

None.

15

Item 6.  Exhibits

The following exhibits are filed herewith or incorporated by reference as indicated below.

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)
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	Bylaws of Registrant (incorporated by reference to Exhibit 3.2 to Registrant’s Form S-4 Registration Statement No. 333-55968 dated December 21, 1992)
3.6	Amendment to Section 3.1 of Bylaws of Registrant adopted October 9, 2003 (incorporated by reference to Exhibit 3.2.1 to Registrant’s Form S-4 Registration Statement No. 333-55968 dated December 21, 1992)
3.7	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)
3.8	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)
3.9	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)
3.10	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)
3.11	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)
3.12	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)
3.13	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)
31.1*	Certification pursuant to Rule 13a-14 and 15d-14 under the Securities Exchange Act of 1934, as amended, of 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
101	Interactive data files pursuant to Rule 405 of Regulation S-T.
*Filed herewith.

16

Signatures

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

	New Concept Energy, Inc.
Date: November 12, 2013	By:	/s/ Gene Bertcher
		Gene S. Bertcher, Principal Executive
		Officer, President and Chief Financial
		Officer

17

EX-31.1

CERTIFICATIONS                                                                                                                     EXHIBIT 31.1

PRINCIPAL EXECUTIVE OFFICER AND CHIEF FINANCIAL OFFICER’S RULE 13a-14(a)/15d-14(a)

I, Gene S. Bertcher, certify that:

1)           I have reviewed this quarterly report on Form 10-Q of New Concept Energy, Inc.;

2)           Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made in light of the circumstances under which such statements were made, and is not misleading with respect to the period covered by this report;

3)           Based on my knowledge, the financial statements and other financial information included in this report fairly present, in all material respects, the financial condition, results of operations and cash flows of the Registrant as of and for the periods presented in this report;

4)           I am responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13-15(e) and 15(d)-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13(a)-15(f) and 15(d)-15(f)) for the Registrant and have:

(a)           Designed such disclosure controls and procedures, or used such disclosure controls and procedures to be designed under my supervision, to ensure that material information relating to the Registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this quarterly report is being prepared;

(b)           Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under my supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principals;

(c)           Evaluated the effectiveness of the Registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the controls and procedures as of the end of the period covered by this report based on such evaluation; and

(d)           Disclosed in this report any change in the Registrant’s internal control over financial reporting that occurred during the Registrant’s most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Registrant’s internal control over financial reporting.

5)           I have disclosed, based on my most recent evaluation of internal control over financial reporting, to the Registrant’s auditors and the audit committee of Registrant’s board of directors (or persons performing the equivalent functions):

(a)           All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the Registrant’s ability to record, process, summarize and report financial information; and

(b)           Any fraud, whether or not material, that involves management or other employees who have a significant role in the Registrant’s internal controls.

Dated: November 12, 2013

/s/ Gene S. Bertcher                                           

Gene S. Bertcher, Principal Executive

Officer, President and Chief Financial Officer

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO 18 U.S.C. § 1350, AS ADOPTED

PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of New Concept Energy, Inc. (the “Company”) of Form 10-Q for the period ended September 30, 2013, as filed with the Securities Exchange Commission on the date hereof (the “Report”), I, Gene S. Bertcher, President and Chief Financial Officer of the Company, do hereby certify pursuant to 18 U.S.C. §1350 that:

(i)           The Report fully complies with the requirements of Section 13(a) or I 5(d) of the Securities Exchange Act of 1934, as amended; and

(ii)           The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company, at the end of the period indicated and for the periods indicated.

Dated:     November 12, 2013

/s/ Gene S. Bertcher

Gene S. Bertcher, Principal Executive

Officer, President and Chief Financial Officer

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Prime Income Asset Management, Inc (Details) (USD $)	3 Months Ended			9 Months Ended
	Dec. 31, 2012	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2013
Prime Income Asset Management, Inc
Company recorded a reserveagainst the receivable in millions			10
Company incurred obligations to Pillar totaling approximately in millions			1.7
Pillar agreed to relieve the Company of its obligation to pay in millions		1.7
Company recorded a gain on the transaction in millions		1.7
Pillar incurred expenses on behalf of the Company	$ 376,000			$ 1,143,000
The Company recorded an additional gain	$ 376,000			$ 1,143,000

XML

Unaudited Statements of Operations (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Revenues:
Oil and gas operations, net of royalties	$ 324	$ 274	$ 1,048	$ 889
Real estate operations	694	702	2,040	2,039
Total Revenues	1,018	976	3,088	2,928
Oil and gas operations	495	432	1,444	1,356
Real estate operations,	372	359	1,141	1,078
Lease expense	235	231	707	693
Corporate general and administrative	170	108	513	402
Accretion of asset retirement obligation	0	0	0	68
Impairment of natural gas and oil properties	0	0	0	912
Total Operating expenses	1,272	1,130	3,805	4,509
Operating earnings (loss)	(254)	(154)	(717)	(1,581)
Interest income	1	0	9	0
Interest expense	(24)	(52)	(97)	(170)
Recovery of bad debt expense	410	1,726	1,143	1,700
Other income (expense), net	0	0	(36)	135
Other income (expense)	387	1,674	1,019	1,665
Net income (loss) applicable to common shares	$ 133	$ 1,520	$ 302	$ 84
Net income (loss) per common share-basic and diluted	$ 0.07	$ 0.78	$ 0.16	$ 0.04
Weighted average common and equivalent shares outstanding - basic	1,947	1,947	1,947	1,947

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RECEIVABLE FROM PRIME INCOME ASSET MANAGEMENT

9 Months Ended

Sep. 30, 2013

RECEIVABLE FROM PRIME INCOME ASSET MANAGEMENT

RECEIVABLE FROM PRIME INCOME ASSET MANAGEMENT

NOTE E – RECEIVABLE FROM PRIME INCOME ASSET MANAGEMENT

Prime Income Asset Management, Inc (“PIAMI”), a related party, is a real estate management company that also invests in real estate for its own account. PIAMI is indirectly owned by a private trust. URC Energy, Inc is and has been a significant investor in the Company. URC Energy, Inc is indirectly owned by a private trust. While the two trusts are separate they have similar trustees and beneficiaries and therefore the Company has noted PIAMI as a related party.

Beginning in 2006 the Company made loans to certain related parties at interest rates higher than the Company believes it could have gotten elsewhere. For a more complete discussion of history of the receivable, the establishment of a reserve due to concerns regarding collectability if the receivable and the recovery efforts refer to the Company’s Annual Report on Form 10-K for the year ended December 31, 2012, in Item 13 on page 26 and Footnote C on page 45.

In the fourth quarter of 2011 the Company determined that the financial condition of PIAMI had deteriorated and there could be no assurance that the amount owed would or could be collected. In 2011, the Company recorded a reserve of $10 million and fully reserved the receivable. Any future collections of the receivable will be reflected as income in the period in which it is collected.

Beginning in 2011 the Company conducted business with Pillar Income Asset Management (“Pillar”), a related party, whereby Pillar would provide the Company with services including processing Payroll, acquiring insurance etc. The Company believes that by purchasing these services through certain large entities it can get lower costs and better service. Pillar has not charged the Company a fee for providing these services.

While separate companies both PIAMI and Pillar are both owned by Realty Advisors, Inc. (“RAI”).  During 2011 and 2012 the Company incurred obligations to Pillar totaling approximately $1.7 million. In a joint agreement among Pillar, PIAMI, RAI and the Company, Pillar agreed to relieve the Company of its obligation to pay $1.7 million and the Company agreed to reduce the amount owed by Prime by a like amount. In the third quarter of 2012 the Company recorded a $1.7 million gain on the transaction. In the fourth quarter of 2012 Pillar incurred expenses on behalf of the Company of $376,000 and agreed to forego payment in exchange for a reduction in the PIAMI obligation. The Company recorded an additional $376,000 gain.

For the nine months ended September 30, 2013 Pillar incurred expenses on behalf of the Company of $1,143,000 and agreed to forego payment in exchange for a reduction in PIAMI obligation. The Company recorded an additional $1,143,000 gain.

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Carlton Energy Group, LLC contingencies (Details)	Feb. 14, 2012	Dec. 31, 2009
Carlton Energy Group, LLC contingencies
The Trial Court reduced the actual damages found by the jury in millions		66.5
The individual jointly and severally liability in actual damages on its tortuous-interference claim in millions		31.16
Assessed exemplary damages against The individual and EurEnergy each in the amount in millions		8.5
Reinstated the jury award of actual damages jointly and severely against the individual and EurEnergy in the amount in millions	66.5

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BASIS OF PRESENTATION

9 Months Ended

Sep. 30, 2013

BASIS OF PRESENTATION:

BASIS OF PRESENTATION

NOTE A: BASIS OF PRESENTATION

The accompanying unaudited consolidated financial statements include the accounts of New Concept Energy, Inc. and its majority-owned subsidiaries (collectively, “NCE” or the “Company”).  All significant intercompany transactions and accounts have been eliminated.  

The unaudited financial statements included herein have been prepared by the Company without audit, pursuant to the rules and regulations of the Securities and Exchange Commission.  The financial statements reflect all adjustments that are, in the opinion of management, necessary to fairly present such information.  All such adjustments are of a normal recurring nature.  Although the Company believes that the disclosures are adequate to make the information presented not misleading, certain information and footnote disclosures, including a description of significant accounting policies normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America, have been condensed or omitted pursuant to such rules and regulations.

These financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ending December 31, 2012.  Operating results for the nine month period ended September 30, 2013 are not necessarily indicative of the results that may be expected for any subsequent quarter or for the fiscal year ending December 31, 2013.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

9 Months Ended

Sep. 30, 2013

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

NOTE C: SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

We consider accounting policies related to our estimates of depreciation amortization and depletion, segments, oil and gas properties, oil and gas reserves, gas gathering assets, office and field equipment, revenue recognition and gas imbalances, leases, revenue recognition for real estate operations, impairment, and sales of real estate as significant accounting policies.  The policies include significant estimates made by management using information available at the time the estimates are made.  However, these estimates could change materially if different information or assumptions were used.  These policies are summarized in our Annual Report on Form 10-K for the year ended December 31, 2012.

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CONTINGENCIES

9 Months Ended

Sep. 30, 2013

CONTINGENCIES

CONTINGENCIES

NOTE F: CONTINGENCIES

Carlton Energy Group, LLC

In December 2006, Carlton Energy Group, LLC (“Carlton”) instituted litigation against an individual, EurEnergy Resources Corporation (“EurEnergy”) and several other entities including New Concept Energy, Inc., which was then known as CabelTel International Corporation (the “Company”) alleging tortuous conduct, breach of contract and other matters and as to the Company that it was the alter ego of EurEnergy. The Carlton claims were based upon an alleged tortuous interference with a contract by the individual and EurEnergy related to the right to explore a coal bed methane concession in Bulgaria which had never (and has not to this day) produced any hydrocarbons. At no time during the pendency of this project or since did the company or any of its officers or directors have any interest whatsoever in the success or failure of the so-called “Bulgaria Project”. However, in the litigation, Carlton alleged that the Company was the alter-ego of certain of the other Defendants including EurEnergy.

Following a jury trial in 2009, the Trial Court (295th District Court of Harris County, Texas) reduced the actual damages found by the jury of $66.5 million and entered judgment against EurEnergy and The individual jointly and severally for $31.16 million in actual damages on its tortuous-interference claim and the Court further assessed exemplary damages against The individual and EurEnergy in the amount of $8.5 million each. The Court granted a judgment for the Company that it was not the alter ego of any of the other parties and thereby would not incur any damages.

Cross appeals were filed by Carlton, the individual and EurEnergy to the Court of Appeals for the First District of Texas (the “Court of Appeals”) which rendered its opinion on February 14, 2012.  The Court of Appeals opinion, among other things, reinstated the jury award of actual damages jointly and severely against the individual and EurEnergy in the amount of $66.5 million and overturned the Trial Court’s ruling favorable to the Company rendering a judgment for that amount plus exemplary damages against the Company as the “alter ego” of EurEnergy.

 The Company, and the other defendants, filed a Petition for Review of the Court of Appeals Opinion with the Supreme Court of the State of Texas. After requesting a response from the Plaintiff the Supreme Court requested full briefing on the merits. In March 2013 the Supreme Court granted the Petition for Review and the Supreme Court heard oral arguments on the matter in September 2013. The parties are awaiting the ruling by the Supreme Court.

The Company vigorously denies that it is the “alter ego” of any other entity; further the Company strongly believes that the Court of Appeals opinion is erroneous in concluding that the Company is an “alter ego” of any other entity which is contrary to Nevada substantive law. There are also questions regarding the underlying liability of EurEnergy and if EurEnergy is successful in its petition for review or, even if unsuccessful if the Company is successful on its positions described above, the Trial Court’s judgment could be reinstated and the Company would have no liability on this claim.

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.

In March 2011, Chesapeake received a summary judgment award including prejudgment interest for $686,874 plus $65,000 in legal fees. The judgment did however acknowledge that the plaintiff did not pay the company for it’s pro rata share of the gas produced by the two wells.

The Company appealed the judgment to the Court of Appeals which reduced the judgment by approximately $16,000 but otherwise affirmed the lower court ruling. The company filed an appeal with the Texas Supreme Court however on February 15, 2013 the Supreme Court denied the petition.

The Company is pursuing its legal remedies to offset the revenue for gas that has been previously produced and held by Chesapeake against the amount due Chesapeake. The Company has recorded a liability due Chesapeake which it believes is sufficient to provide for the net obligation to Chesapeake.

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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OIL AND GAS RESERVES

9 Months Ended

Sep. 30, 2013

OIL AND GAS RESERVES

OIL AND GAS RESERVES

NOTE D: OIL AND GAS RESERVES

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.

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 a standardized method for determining pricing and require that future cash flow be discounted using a 10% rate. The valuation that results may not represent management’s estimated current market value of proved reserves.

During the past few years the exploration, development and production of natural gas has resulted in an oversupply of natural gas which has resulted in a substantial reduction in the market price. Management of the Company believes that this oversupply will last for some time and does not anticipate an increase in the price we can receive in the market place. In April 2012 the Company entering into an agreement to fix the price it receives for the sale of its gas. For the five years ended April 2017 the Company will receive $4.53 per MCF. While the lock-in price is higher than the current market price for natural gas when applying the new price using the formula mandated by the accounting rules the result was a reduction of $912,000 in value of the Company’s recorded interests in its oil and gas properties. This reduction in value was reflected in financial statements of the company as of March 2012.

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Balance Sheets Parentheticals (USD $)	Sep. 30, 2013	Dec. 31, 2012
Parentheticals
Preferred Stock	$ 1	$ 1
Prefrred Stock, shares authorized	10,000,000	10,000,000
Common Stock	$ 0.1	$ 0.1
Common Stock, shares authorized	100,000,000	100,000,000
Common Stock, shares issued	1,946,935	1,946,935
Common Stock, shares Outstanding	1,946,935	1,946,935

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SUBSEQUENT EVENTS

9 Months Ended

Sep. 30, 2013

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS

NOTE I:  SUBSEQUENT EVENTS

The Company has evaluated subsequent events through November 6, 2013, the date the financial statements were available to be issued, and has determined that there are none to be reported.

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Unaudited Statements of Cash Flows (USD $)	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Cash flows from operating activities:
Net income	$ 302	$ 84
Adjustments to reconcile net income to net cash provided by (used in) operating activities
Depreciation, depletion and amortization	687	570
Accretion of asset retirement obligation	0	158
Write-off (recovery) of affiliate receivable	(1,143)	(1,700)
Changes in operating assets and liabilities
Other current and non-current assets	(110)	(277)
Accounts payable and other liabilities	1,341	521
Impairment of oil and gas properties	0	912
Net cash provided by (used) in operating activities	1,077	268
Cash flows from investing activities
Investment in oil and gas	(82)	(79)
Fixed asset additions	(150)	(71)
Net cash provided by (used in) investing activities	(232)	(150)
Cash flows from financing activities
Proceeds from loans	62	42
Payment on notes payable	(29)	(34)
Net cash provided by (used in) financing activities	33	8
Net increase (decrease) in cash and cash equivalents	878	126
Cash and cash equivalents at beginning of year	398	109
Cash and cash equivalents at end of year	$ 1,276	$ 235

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Balance Sheets (USD $)	Sep. 30, 2013	Dec. 31, 2012
Current Assets
Cash and cash equivalents	$ 1,276	$ 398
Accounts receivable from oil and gas sales	233	210
Other current assets	7	2
Total current assets	1,516	610
Oil and natural gas properties (full cost accounting method)
Proved developed and undeveloped oil and gas properties, net of depletion	9,294	9,717
Property and equipment, net of depreciation
Land, buildings and equipment - oil and gas operations	1,461	1,410
Other	193	204
Total property and equipment	1,654	1,614
Other assets (including $120,750 and $161,300 due from related parties in 2013 and 2012	590	543
Total assets	13,054	12,484
Current liabilities
Accounts payable - trade	119	38
Accrued expenses	289	173
Current portion of long term debt	53	93
Total current liabilities	461	304
Long-term debt
Notes payable less current portion	2,334	2,273
Asset retirement obligation	2,770	2,770
Other long-term liabilities	541	491
Total liabilities	6,106	5,838
Stockholders' equity
Preferred stock, Series B	1	1
Common stock, $.01 par value; authorized, 100,000,000 shares; issued and outstanding, 1,946,935 shares at June 30, 2013 and December 31, 2012	20	20
Additional paid-in capital	58,838	58,838
Accumulated deficit	(51,911)	(52,213)
Total Stockholders' equity	6,948	6,646
Total liabilities & equity	$ 13,054	$ 12,484

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Segmant report Information for Nine months ended September 30, 2012 (Details) (USD $)	Oil and Gas Operations'	Retirement Facility'	Corporate segment'	Total segments'
Operating Segments balance for Nine months ended September 30, 2012. at Dec. 31, 2011
Segment Operating revenue for Nine months ended September 30, 2012	$ 889	$ 2,039		$ 2,928
Segment Operating expenses for Nine months ended September 30, 2012	850	1,040	402	2,292
Segment Depreciation, Depletion and Amortization for Nine months ended September 30, 2012	506	38		544
Segment Lease Expense for Nine months ended September 30, 2012		693		693
Segment Accretion of Asset Retirement Obligation for Nine months ended September 30, 2012	68			68
Segment Impairment of Natural Gas and Oil Properties	912			912
Segment Total Operating Expenses for Nine months ended September 30, 2012	2,336	1,771	402	4,559
Segment Interest expense for Nine months ended September 30, 2012	(170)			(170)
Segment Recovery of Bad Debt Expense for Nine months ended September 30, 2012	1,700	1,700
Segment Other income for Nine months ended September 30, 2012			135	135
Segment operating income for Nine months ended September 30, 2012	(1,617)	268	1,433	84
Operating Segments balance for Nine months ended September 30, 2012. at Sep. 30, 2012	$ 0

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NEWLY ISSUED ACCOUNTING STANDARDS

9 Months Ended

Sep. 30, 2013

NEWLY ISSUED ACCOUNTING STANDARDS

NEWLY ISSUED ACCOUNTING STANDARDS

 NOTE H:  NEWLY ISSUED ACCOUNTING STANDARDS

We have considered all other newly issued accounting guidance that is applicable to our operations and the preparation of our consolidated statements, including that which we have not yet adopted.  We do not believe that any such guidance will have a material effect on our financial position or results or operation.

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OIL AND GAS RESERVES REDUCTION IN VALUE (Details) (USD $)	Sep. 30, 2013	Apr. 30, 2012
OIL AND GAS RESERVES REDUCTION IN VALUE:
Fixed price per MCF on sale of its natural gas	0	4.53
Reduction of interest in oil and gas properties	$ 912,000	$ 0

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OPERATING SEGMENTS

9 Months Ended

Sep. 30, 2013

OPERATING SEGMENTS

OPERATING SEGMENTS

NOTE G:  OPERATING SEGMENTS

The following table reconciles the segment information to the corresponding amounts in the Consolidated Statements of Operations and total assets:

Three months ended September 30, 2013	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	324		$	694	$	-	$	1,018
Operating expenses		308			357		170		835
Depreciation, depletion and amortization		187			15		-		202
Lease expense		-			235		-		235
Total operating expenses		495			607		170		1,272
Interest income		-			-		1		1
Interest expense		(24	)		-		-		(24	)
Recovery of bad debt expense		-			-		410		410
Other income		-			-		-		-
Segment operating income	$	(195	)	$	87	$	241	$	133

Three months ended September 30, 2012	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	274		$	702	$	-	$	976
Operating expenses		264			341		108		713
Depreciation, depletion and amortization		168			18		-		186
Lease expense		-			231		-		231
Accretion of asset retirement obligation		-			-		-		-
Total operating expenses		432			590		108		1,130
Interest expense		(52	)		-		-		(52	)
Recovery of bad debt expense		-			-		1,700		1,700
Other income		-			-		26		26
Segment operating income	$	(210	)	$	112	$	1,618	$	1,520

Nine months ended September 30, 2013	Oil and Gas Operations			Retirement Facility		Corporate			Total
Operating revenue	$	1,048		$	2,040	$	-		$	3,088
Operating expenses		874			1,096		513			2,483
Depreciation, depletion and amortization		570			45		-			615
Lease expense		-			707		-			707
Total operating expenses		1,444			1,848		513			3,805
Interest income		-			-		9			9
Interest expense		(97	)		-		-			(97	)
Recovery of bad debt expense		-			-		1,143			1,143
Other income		-			-		(36	)		(36	)
Segment operating income	$	(493	)	$	192	$	603		$	302

Nine months ended September 30, 2012	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	889		$	2,039	$	-	$	2,928
Operating expenses		850			1,040		402		2,292
Depreciation, depletion and amortization		506			38		-		544
Lease expense		-			693		-		693
Accretion of asset retirement obligation		68			-		-		68
Impairment of natural gas and oil properties		912			-		-		912
Total operating expenses		2,336			1,771		402		4,509
Interest expense		(170	)		-		-		(170	)
Recovery of bad debt expense		-			-		1,700		1,700
Other income		-			-		135		135
Segment operating income	$	(1,617	)	$	268	$	1,433	$	84

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NATURE OF OPERATIONS

9 Months Ended

Sep. 30, 2013

NATURE OF OPERATIONS

NATURE OF OPERATIONS

NOTE B: NATURE OF OPERATIONS

The Company 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.

The Company also leases and operates a retirement community in King City Oregon, with a capacity of 114 residents.

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Chesapeake Exploration Limited Partnership and Chesapeake Operating, Inc (Details) (USD $)	Mar. 31, 2011	Jan. 31, 2006
Chesapeake Exploration Limited Partnership and Chesapeake Operating, Inc
Company entered into a joint operating agreement evidencing its acquisition of a interest in two gas wells		5.00%
Subsequent to its investment, the Company received an invoice from Chesapeake for		$ 556,217
Chesapeake received a summary judgment award	686,874
Chesapeake received a prejudgment interest	65,000
The Company appealed the judgment to the Court of Appeals which reduced the judgment by approximately	$ 16,000

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Operating Income And Expenses (Tables)

9 Months Ended

Sep. 30, 2013

Operating Income And Expenses:

Operating Income And Expenses

The following table reconciles the segment information to the corresponding amounts in the Consolidated Statements of Operations and total assets:

Three months ended September 30, 2013	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	324		$	694	$	-	$	1,018
Operating expenses		308			357		170		835
Depreciation, depletion and amortization		187			15		-		202
Lease expense		-			235		-		235
Total operating expenses		495			607		170		1,272
Interest income		-			-		1		1
Interest expense		(24	)		-		-		(24	)
Recovery of bad debt expense		-			-		410		410
Other income		-			-		-		-
Segment operating income	$	(195	)	$	87	$	241	$	133

Three months ended September 30, 2012	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	274		$	702	$	-	$	976
Operating expenses		264			341		108		713
Depreciation, depletion and amortization		168			18		-		186
Lease expense		-			231		-		231
Accretion of asset retirement obligation		-			-		-		-
Total operating expenses		432			590		108		1,130
Interest expense		(52	)		-		-		(52	)
Recovery of bad debt expense		-			-		1,700		1,700
Other income		-			-		26		26
Segment operating income	$	(210	)	$	112	$	1,618	$	1,520

Nine months ended September 30, 2013	Oil and Gas Operations			Retirement Facility		Corporate			Total
Operating revenue	$	1,048		$	2,040	$	-		$	3,088
Operating expenses		874			1,096		513			2,483
Depreciation, depletion and amortization		570			45		-			615
Lease expense		-			707		-			707
Total operating expenses		1,444			1,848		513			3,805
Interest income		-			-		9			9
Interest expense		(97	)		-		-			(97	)
Recovery of bad debt expense		-			-		1,143			1,143
Other income		-			-		(36	)		(36	)
Segment operating income	$	(493	)	$	192	$	603		$	302

Nine months ended September 30, 2012	Oil and Gas Operations			Retirement Facility		Corporate		Total
Operating revenue	$	889		$	2,039	$	-	$	2,928
Operating expenses		850			1,040		402		2,292
Depreciation, depletion and amortization		506			38		-		544
Lease expense		-			693		-		693
Accretion of asset retirement obligation		68			-		-		68
Impairment of natural gas and oil properties		912			-		-		912
Total operating expenses		2,336			1,771		402		4,509
Interest expense		(170	)		-		-		(170	)
Recovery of bad debt expense		-			-		1,700		1,700
Other income		-			-		135		135
Segment operating income	$	(1,617	)	$	268	$	1,433	$	84

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Segmant report Information for Nine months ended September 30, 2013 (Details) (USD $)	Oil and Gas Operations .	Retirement Facility.	Corporate segment .	Total segments.
Operating Segments balance for Nine months ended September 30, 2013 at Dec. 31, 2012	$ 0
Segment Operating revenue for Nine months ended September 30, 2013	1,048	2,040		3,088
Segment Operating expenses for Nine months ended September 30, 2013	874	1,096	513	2,483
Segment Depreciation, Depletion and Amortization for Nine months ended September 30, 2013	570	45		615
Segment Lease Expense for Nine months ended September 30, 2013		707		707
Segment Total Operating Expenses for Nine months ended September 30, 2013	1,444	1,848	513	3,805
Segment Interest Incomefor Nine months ended September 30, 2013			9	9
Segment Interest expense for Nine months ended September 30, 2013	(97)			(97)
Segment Recovery of Bad Debt Expense for Nine months ended September 30, 2013			1,143	1,143
Segment Other income for Nine months ended September 30, 2013			(36)	(36)
Segment operating income for Nine months ended September 30, 2013	(493)	192	603	302
Operating Segments balance for Nine months ended September 30, 2013. at Sep. 30, 2013	$ 0

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Segmant report Information for Three months ended September 30, 2013 (Details) (USD $)	Oil and Gas Operations	Retirement Facility	Corporate segment	Total segments
Operating Segments balance at Jun. 30, 2013
Segment Operating revenue	$ 324	$ 694		$ 1,018
Segment Operating expenses	308	357	170	835
Segment Depreciation, Depletion and Amortization	187	15		202
Segment Lease Expense		235		235
Segment Total Operating Expenses	495	607	170	1,272
Segment Interest Income			1	1
Segment Interest expense	(24)			(24)
Segment Recovery of Bad Debt Expense			410	410
Segment Other income	0		0	0
Segment operating income	(195)	87	241	133
Operating Segments balance at Sep. 30, 2013	$ 0

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Document and Entity Information	9 Months Ended
	Sep. 30, 2013	Nov. 06, 2013
Document and Entity Information:
Entity Registrant Name	New Concept Energy, Inc.
Document Type	10-Q
Document Period End Date	Sep. 30, 2013
Amendment Flag	false
Entity Central Index Key	0000105744
Current Fiscal Year End Date	--12-31
Entity Common Stock, Shares Outstanding		1,946,935
Entity Filer Category	Smaller Reporting Company
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	No
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3

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Segmant report Information for Three months ended September 30, 2012 (Details) (USD $)	Oil and Gas Operations ,	Retirement Facility ,	Corporate segment ,	Total segments ,
Operating Segments balance for Three months ended September 30, 2012 at Jun. 30, 2012	$ 0
Segment Operating revenue for Three months ended September 30, 2012	274	702		976
Segment Operating expenses for Three months ended September 30, 2012	264	341	108	713
Segment Depreciation, Depletion and Amortization for Three months ended September 30, 2012	168	18		186
Segment Lease Expense for Three months ended September 30, 2012		231		231
Accretion of Asset Retirement Obligation	0			0
Segment Total Operating Expenses for Three months ended September 30, 2012	432	590	108	1,130
Segment Interest expense for Three months ended September 30, 2012	(52)			(52)
Segment Recovery of Bad Debt Expense for Three months ended September 30, 2012			1,700	1,700
Segment Other income for Three months ended September 30, 2012			26	26
Segment operating income for Three months ended September 30, 2012	(210)	112	1,618	1,520
Operating Segments balance for Three months ended September 30, 2012, at Sep. 30, 2012	$ 0