UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 20549

FORM 10-Q

(Mark One)

For the Quarterly Period Ended JuneSeptember 30, 2014

Commission File Number 0-8157

THE RESERVE PETROLEUM COMPANY

 (Exact Name of Registrant as Specified in Its Charter)

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 ☒   No ☐

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 ☒   No ☐

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

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

As of August 8,November 7, 2014, 158,826158,700 shares of the Registrant’s $.50 par value common stock were outstanding.

PART I – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

THE RESERVE PETROLEUM COMPANY

BALANCE SHEETS

ASSETS

See Accompanying Notes

THE RESERVE PETROLEUM COMPANY

BALANCE SHEETS

LIABILITIES AND STOCKHOLDERS’ EQUITY

See Accompanying Notes

THE RESERVE PETROLEUM COMPANY

STATEMENTS OF INCOME

(Unaudited)

See Accompanying Notes

THE RESERVE PETROLEUM COMPANY

CONDENSED STATEMENTS OF CASH FLOWS

(Unaudited)

See Accompanying Notes

THE RESERVE PETROLEUM COMPANY 

NOTES TO FINANCIAL STATEMENTS

JuneSeptember 30, 2014 

(Unaudited)

Note 1 – BASIS OF PRESENTATION

The accompanying balance sheet as of December 31, 2013, which has been derived from audited financial statements, the unaudited interim financial statements and these notes, have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Accordingly, certain disclosures normally included in financial statements prepared in accordance with the accounting principles generally accepted in the United States of America (“GAAP”) have been omitted. The accompanying financial statements and notes thereto should be read in conjunction with the financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2013.

In the opinion of Management, the accompanying financial statements reflect all adjustments (consisting only of normal recurring accruals), which are necessary for a fair statement of the results of the interim periods presented. The results of operations for the current interim periods are not necessarily indicative of the operating results for the full year.

Note 2 – OTHER INCOME / (LOSS), NET

The following is an analysis of the components of Other Income/Income / (Loss), Net:

Note 3 – INVESTMENTS AND RELATED COMMITMENTS AND CONTINGENT LIABILITIES, INCLUDING GUARANTEES

Equity Investment consists of a 33% ownership interest in Broadway Sixty-Eight, Ltd. (the “Partnership”), an Oklahoma limited partnership, which owns and operates an office building in Oklahoma City, Oklahoma. Although the Company invested as a limited partner, it agreed, jointly and severally, with all other limited partners to reimburse the general partner for any losses suffered from operating the Partnership. The indemnity agreement provides no limitation to the maximum potential future payments. To date, no monies have been paid with respect to this agreement.

Note 4 – PROVISION FOR INCOME TAXES

In 2014 and 2013, the effective tax rate was less than the statutory rate, primarily as a result of allowable depletion for tax purposes in excess of the cost basis in oil and gas properties and the corporate graduated tax rate structure.

Excess federal percentage depletion, which is limited to certain production volumes and by certain income levels, reduces estimated taxable income projected for any year. The federal excess percentage depletion estimates arewill be updated throughout the year until finalized with the detail well-by-well calculations at year-end. When a provision for income taxes is recorded, federal excess percentage depletion benefits decrease the effective tax rate. The benefit of federal excess percentage depletion is not directly related to the amount of pre-tax income recorded in a period. Accordingly, in periods where a recorded pre-tax income is relatively small, the proportional effect of these items on the effective tax rate may be significant.

Note 5 – ASSET RETIREMENT OBLIGATION

The Company records the fair value of its estimated liability to retire its oil and natural gas producing properties in the period in which it is incurred (typically the date of first sale). The estimated liability is calculated by obtaining current estimated plugging costs from the well operators and inflating it over the life of the property. Current year inflation rate used is 4.08%. When the liability is first recorded, a corresponding increase in the carrying amount of the related long-lived asset is also recorded. Subsequently, the asset is amortized to expense over the life of the property and the liability is increased annually for the change in its present value which is currently 3.25%.

A reconciliation of the Company’s asset retirement obligation liability is as follows:

Note 6 – FAIR VALUE MEASUREMENTS

Inputs used to measure fair value are organized into a fair value hierarchy based on the observability of the inputs. Level 1 inputs consist of quoted prices in active markets for identical assets. Level 2 inputs are inputs, other than quoted prices, for similar assets that are observable. Level 3 inputs are unobservable inputs.

Recurring Fair Value Measurements

Certain of the Company’s assets are reported at fair value in the accompanying balance sheets on a recurring basis. The Company determined the fair value of the available-for-sale securities using quoted market prices for securities with similar maturity dates and interest rates. At JuneSeptember 30, 2014 and December 31, 2013, the Company’s assets reported at fair value on a recurring basis are summarized as follows:

Non-Recurring Fair Value Measurements

The Company’s asset retirement obligation annually represents a non-recurring fair value liability. The fair value of the non-financial liability incurred in the sixnine months ended JuneSeptember 30, was $32,272$48,246 in 2014 and $61,726$80,588 in 2013 and was calculated using Level 3 inputs. See Note 5 above for more information about this liability and the inputs used for calculating fair value.

Fair Value of Financial Instruments

The Company’s financial instruments consist primarily of cash and cash equivalents, trade receivables, marketable securities, trade payables and dividends payable. At JuneSeptember 30, 2014 and December 31, 2013, the historical cost of cash and cash equivalents, trade receivables, trade payables and dividends payable are considered to be representative of their respective fair values due to the short-term maturities of these items.

Note 7 – SUBSEQUENT EVENTS

On July 30,September 24, 2014, the Company received $659,255 assigned a bonussubscription for 500,000 units of Cloudburst Solutions LLC, a leasewastewater purification technology company, at $1.00 per unit for the sum of 366 net acres$500,000, which was paid in October. This investment is not expected to have a material effect on the Company’s financial position, results of owned minerals in Lee County, Texas.operations or cash flows. This amount will be reflected as lease bonus revenue in the 2014 third quarter results includedOther Investments in the Company’s Form 10-Q Quarterly Report10-K for the periodyear ending September 30,December 31, 2014.

Note 8 – NEW ACCOUNTING PRONOUNCEMENTS

In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, “Revenue from Contracts with Customers” (“ASU 2014-09”).Customers.” ASU 2014-09 clarifies the principles for recognizing revenue and develops a common revenue standard under U.S. GAAP under which an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. ASU 2014-09 is effective for the Company for interim and annual periods beginning on or after December 15, 2016. Management is currently assessing the impact ASU 2014-09 will have on the Company, but it is not expected to have a material effect on the Company’s financial position, results of operations or cash flows.

In August 2014, the FASB issued ASU 2014-15 requiring management to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the entity’s ability to continue as a going concern, which is currently performed by the external auditors. Management will be required to perform this assessment for both interim and annual reporting periods and must make certain disclosures if it concludes that substantial doubt exists. This ASU is effective for annual periods, and interim periods within those annual periods, beginning on or after December 15, 2016. The adoption of this guidance is not expected to have any effect on the Company’s financial statements.

No other accounting pronouncements were issued and none became effective since December 31, 2013 that were directly applicable to the Company.

This discussion and analysis should be read with reference to a similar discussion in the Company’s Annual Report on Form 10-K for the year ended December 31, 2013 as filed with the Securities and Exchange Commission (hereinafter, the “2013 Form 10-K”), as well as the financial statements included in this Form 10-Q.

Forward Looking Statements

This discussion and analysis includes forward looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Forward looking statements give the Company’s current expectations of future events. They include statements regarding the drilling of oil and gas wells, the production that may be obtained from oil and gas wells, cash flow and anticipated liquidity and expected future expenses.

Although management believes the expectations in these and other forward looking statements are reasonable, we can give no assurance they will prove to have been correct. They can be affected by inaccurate assumptions or by known or unknown risks and uncertainties. Factors that would cause actual results to differ materially from expected results are described under “Forward Looking Statements” on page 8 of the 2013 Form 10-K.

We caution you not to place undue reliance on these forward looking statements, which speak only as of the date of this Form 10-Q, and we undertake no obligation to update this information. You are urged to carefully review and consider the disclosures made in this and our other reports filed with the Securities and Exchange Commission that attempt to advise interested parties of the risks and factors that may affect our business.

Financial Conditions and Results of Operations

Liquidity and Capital Resources

Please refer to the Balance Sheets and the Condensed Statements of Cash Flows in this Form 10-Q to supplement the following discussion. In the first halfnine months of 2014, the Company continued to fund its business activity through the use of internal sources of cash.

The Company had cash provided by operations of $7,216,668$10,445,464 and cash provided by the maturities of available-for-sale securities of $6,653,823. Additional cash of $308,783$358,927 was provided by property dispositions and an investment distributionsdistribution for total cash provided of $14,179,274.$17,458,214. The Company utilized cash for the purchase of available-for-sale securities of $6,654,786,$6,654,786; property additions of $2,528,483$3,527,021; other investments of $27,125; and financing activities of $3,120,029$3,195,253 for total cash applied of $12,303,298.$13,404,185. Cash and cash equivalents increased $1,875,976 (17%)$4,054,029 to $12,640,482.$14,818,535.

Discussion of Significant Changes in Working Capital. In addition to the changes in cash and cash equivalents discussed above, there were other changes in working capital line items from December 31, 2013. A discussion of these items follows.

Trading securities decreased $77,654 (13%) from $586,708 to $509,054. The decrease was the net result of a $109,604 decrease in the trading securities’ market value, offset by $31,950 of net income from these securities.

Refundable income taxes decreased $153,184 (46%increased $208,071 (62%) to $183,436 from $336,620 to $544,691. This increase was due primarily to the first halfestimated tax payments of $2,170,145 for the nine months ended September 30, 2014, offset by the current income tax provision of $1,623,195, offset by estimated tax payments of $1,470,011 for the same period.period of $1,962,074.

Accounts payable increased $113,917 (31%$1,359,973 (370%) to $481,539$1,727,595 from $367,622. TheThis increase was due entirelypartly to the increasedan increase in drilling activity at JuneSeptember 30, 2014 compared toversus December 31, 2013. Most of the increase at September 30, 2014 was due to participating in several drilling ventures with operators that did not require advance payments of the estimated costs to drill the wells. At December 31, 2013, most of our participation was with operators requiring prepayments, which is standard industry practice.

Deferred income taxes and other liabilities increased $69,020 (20%$215,580 (64%) to $406,644$553,204 from $337,624$337,624. The increase is partly due to an increase of $60,000$90,000 in ad valorem tax accruals and an increase of $9,020 in current deferred income taxes.accruals. Ad valorem (property) taxes are primarily for Texas properties and are accrued for the first three quarters each year to be paid in the fourth quarter. Current deferred income taxes accounted for the remaining $125,580 increase.

Discussion of Significant Changes in the Condensed Statements of Cash Flows. As noted in the first paragraph above, net cash provided by operating activities was $7,216,668$10,445,464 in 2014, an increase of $1,759,218 (32%$1,271,587 (14%) from the comparable period in 2013. The increase was primarily due to increased operatingoil and gas sales revenue, partiallypartly offset by increased production, exploration costs.and current income tax expense for 2014 compared to 2013. For more information see “Operating Revenues” and “Exploration Costs”“Operating Costs and Expenses” below.

Cash applied to the purchase of property, additionsplant and equipment in 2014 was $2,528,483,$3,527,021, a decrease of $1,021,733$1,423,341 (29%) from cash applied in 2013 of $3,550,216.$4,950,362. In both 2014 and 2013, cash applied to property, plant and equipment additions was mostly related to oil and gas exploration and development activity. The drilling activity in 2014 is comparable to 2013; however, the increase in accounts payable, discussed above, resulted in the decrease in cash applied to property, plant and equipment additions. See the subheading “Exploration Costs” in the “Results of Operations” section below for additional information.

Cash provided by distributions from equity investee in 2014 were $337,095, an increase of $320,595 from the comparable period in 2013. The increase was due to the distribution by Broadway Sixty-Eight, Ltd. of the profit from 2013 and 2014 sales of several small commercial office buildings. The office buildings were constructed by Broadway Sixty-Eight, Ltd. on some vacant land adjacent to the office building in which our corporate office is located. See Note 3 to the accompanying financial statements for additional information about this equity investment.

Cash applied to the payment of dividends in 2014 was $3,051,808, an increase of $1,403,536 (85%) from cash applied in 2013 of $1,648,272. The increase was due to an increase in the dividends paid to $20.00 per share in 2014 from $10.00 per share in 2013.

Conclusion. Management is unaware of any additional material trends, demands, commitments, events or uncertainties, which would impact liquidity and capital resources to the extent that the discussion presented in the 2013 Form 10-K would not be representative of the Company’s current position.

Material Changes in Results of Operations SixNine Months Ended JuneSeptember 30, 2014, Compared with SixNine Months Ended JuneSeptember 30, 2013

Net income increased $549,554 (16%$1,012,072 (20%) to $4,046,212$6,154,141 in 2014 from $3,496,658$5,142,069 in 2013. Net income per share, basic and diluted, increased $3.66 (17%)$6.63 to $25.43$38.70 in 2014 from $21.77$32.07 in 2013.

A discussion of revenue from oil and gas sales and other significant line items in the statements of income follows.

Operating Revenues. Revenues from oil and gas sales increased $1,598,462 (18%$1,561,261 (12%) to $10,379,177$15,021,426 in 2014 from $8,780,715$13,460,165 in 2013. The $1,598,462Of the $1,561,261 increase, is due to highercrude oil sales increased $149,179; natural gas sales of $777,922; higher crude oil sales of $562,635;increased $1,147,480; and an increase in miscellaneous oil and gas product sales of $257,905.increased $264,602.

The $562,635 (9%$149,179 (2%) increase in oil sales to $6,608,766$9,614,384 in 2014 from $6,046,131 in 2013 was the result of an increase in both the volume sold and the average price per barrel (Bbl). The volume of oil sold increased 353 Bbls to 70,555 Bbls in 2014, resulting in a positive volume variance of $30,404. This volume increase was the net result of an increase of 24,103 Bbls for production that began after June 30, 2013, offset by a decline of 23,750 Bbls from older properties. The average price per Bbl increased $7.54 to $93.67 per Bbl in 2014, resulting in a positive price variance of $532,231.

The $777,922 (30%) increase in gas sales to $3,378,998 in 2014 from $2,601,076$9,465,205 in 2013 was the net result of an increase in the average price per thousand cubic feet (MCF), offset bybarrel (Bbl) and a declinedecrease in the volume sold. The volume of gas sold decreased 25,718 MCF to 719,832 MCF from 745,550 MCF in 2013, for a negative volume variance of $89,756. The decrease in gas volumes sold was the net result of approximately 206,000 MCF of production declines from older wells, especially in Arkansas, partially offset by production of approximately 180,000 MCF from wells that first produced after June 30, 2013. The average price per MCFBbl increased $1.20$2.49 to $4.69$92.80 per MCF from $3.49 per MCFBbl in 2013,2014, resulting in a positive price variance of $867,678.$258,003. The volume of oil sold decreased 1,205 Bbls to 103,598 Bbls in 2014, resulting in a negative volume variance of $108,824. The decrease in oil volumes sold was mostly due to production declines from older wells, offset partially by production of 33,850 Bbls from new wells in Oklahoma, Texas and Kansas.

The $1,147,480 (30%) increase in gas sales to $4,919,568 in 2014 from $3,772,088 in 2013 was the result of increases in the volume sold and the average price per thousand cubic feet (MCF). The volume of gas sold increased 4,076 MCF to 1,083,273 MCF in 2014, for a positive volume variance of $14,266. The average price per MCF increased $1.04 to $4.54 per MCF in 2014, resulting in a positive price variance of $1,133,214. The net increase in gas volumes sold was due to 305,000 MCF of production from several new working and royalty interest wells, offset by a decline in sales from older properties. Roger Mills and Woods County, Oklahoma working interest wells accounted for 237,600 MCF (78%) of the increase in sales volumes for the new wells.

Sales from the Robertson County, Texas royalty interest properties provided approximately 22% of the Company’s first halfnine months 2014 gas sales volumes and about 27% of the first half 2013 gas sales volumes. See discussion on page 11 of the 2013 Form 10-K, under the subheading “Operating Revenues”Revenues,” for more information about these properties. Sales from Arkansas working interest properties provided approximately 19% of the Company’s first half 2014 gas sales volumes and about 33% of the first half 2013 gas sales volumes.

For both oil and gas sales, the price change was mostly the result of a change in the spot market prices, upon which most of the Company’s oil and gas sales are based. These spot market prices have had significant fluctuations in the past and these fluctuations are expected to continue.

Sales of miscellaneous oil and gas products were $391,413$487,474 in 2014 as compared to $133,508$222,872 in 2013.

The Company received lease bonuses of $614,894$1,296,650 in the first halfnine months of 2014 for leases on its owned minerals. Lease bonuses forminerals compared to $172,246 in the first halfnine months of 2013 were $157,033. 2013.

In 2014, 89%95% of the bonuses were for leases on owned minerals, mostly in Lee and Burleson County, Texas and the remainder were for owned minerals in Oklahoma. In 2013, 85%77% of the bonuses were for Oklahoma leases and 15%23% were for Texas leases.

Coal royalties were $1,443 for the first nine months of 2014 and 2013 on North Dakota leases. See subheading “Operating Revenues” on page 11 of the 2013 Form 10-K for more information about this property.

Operating Costs and Expenses. Operating costs and expenses increased $1,379,533 (32%$1,111,333 (16%) to $5,721,656$8,130,958 in 2014 from $4,342,123$7,019,625 in 2013. Material line item changes are discussed and analyzed in the following paragraphs.

Production Costs. Production costs increased $253,051 (18%$318,575 (15%) to $1,662,489$2,453,924 in 2014 from $1,409,438$2,135,349 in 2013. Lease operating expense and transportation and compression expense increased $166,619 (15%)$214,882 to $1,242,344$1,857,089 in 2014 from $1,075,725$1,642,207 in 20132013. This increase was due primarily to new wells that first produced after JuneSeptember 30, 2013. Production taxes increased $86,432 (26%)$103,693 to $420,145$596,835 in 2014 from $333,713$493,141 in 20132013. This increase was due primarily to the increasedhigher oil and natural gas sales revenues described above in the “Operating Revenues” section.revenue.

Exploration Costs. Total exploration expense increased $921,897 (312%$864,460 (248%) to $1,217,377$1,212,804 in 2014 from $295,480$348,344 in 2013. The increase is due to an increase in both geological and geophysical expense and dry hole costs. Geological and geophysical expenses totaled $663,641 in 2014 as compared to $293,495 in 2013. Dry hole costs increased $553,623$494,314 to $556,560$549,163 in 2014 from $2,937 in 2013. Geological and geophysical expense increased $368,273 to $660,816 in 2014 from $292,543$54,849 in 2013.

The following is a summary as of July 29,October 31, 2014, updating both exploration and development activity from December 31, 2013, for the period ended JuneSeptember 30, 2014.

The Company participated with its 18% working interest in the drilling of three development wells on a Barber County, Kansas prospect. Two of the wells were completed as commercial gas producers and the third as a commercial oil producer. Three additional development wells will be drilled on the prospect in 2014. Capitalized costs for the period were $292,262,$266,251, including $79,042$26,224 in prepaid drilling costs.

The Company participated with 16%, 8% and 8%12% working interests in the drilling of twothree development wells on a Woods County, Oklahoma prospect. BothThe first two wells were completed as commercial oil and gas producers.producers and the third is awaiting completion. An additional development well (16% interest) will be drilled before year-end. Capitalized costs for the period were $175,200, including $5,613$3,098 in prepaid drilling costs.

The Company participated with its 18% working interest in the drilling of a development well on a Woods County, Oklahoma prospect. The well was completed as a commercial gas producer. Capitalized costs for the period were $131,400, including $54,938$37,128 in prepaid drilling costs.

The Company participated with an 11.8% working interest in the drilling of a development well on a Woods County, Oklahoma prospect. A completion isThe well was completed as a commercial oil and gas producer. An additional development well (8% interest) will be drilled starting in progress.November 2014. Capitalized costs for the period were $85,775, including $46,579$87,743.

The Company participated with a 13.7% working interest in prepaidthe drilling costs.of two development wells on a Woods County, Oklahoma prospect. Completions are in progress on both wells. Prepaid drilling costs for the period were $76,534.

The Company participated with its 10.5% working interest in the drilling of an exploratory well on a Cimarron County, Oklahoma prospect. The well was completed as a dry hole. The Company is participating in a salt water disposal well that will allow a well drilled on the prospect last year to be produced and will participate in the drilling of an additional exploratory well starting in December 2014. Capitalized costs for the period were $28,634. Costs expensed to dry hole costs were $60,502.$62,062.

The Company participated with a 7.5% working interest in the drilling of three horizontal development wells on a Woods County, Oklahoma prospect. Completions are in progress on allAll three wells.wells were completed as commercial oil and gas producers. Capitalized costs for the period were $262,589.$808,675.

The Company participated with a 9% working interest in the drilling of two horizontal development wells on a Roger Mills County, Oklahoma prospect. Completions are in progress on both wells.Both wells were completed as commercial gas and condensate producers. Capitalized costs for the period were $151,454.$1,011,413.

The Company will participate with its 10.5% working interest in the drilling of an exploratory well on a Logan County, Oklahoma prospect starting in the third quarter ofNovember 2014.

The Company participated with a 6.6% working interest in the drilling of an exploratory well on a Garvin County, Oklahoma prospect. The deep objectives were non-productive and the lower portion of the hole was plugged. The Company is participating with a 12.8% working interest in a completion attempt of a shallow zone. Capitalized costs for the period were $83,793, including $9,182 in prepaid drilling costs.$96,038. Costs of $482,882 were expensed to dry hole costs.

The Company is participatingparticipated with its 10.5% interest in the purchase of a producing oil well and two salt water disposal wells on a Seminole County, Oklahoma prospect. One of the disposal wells will behas been recompleted as an oil producer. Previous plansA pipeline will be constructed from the producing wells to drill a producing well have been delayed indefinitely, and the previously plannedremaining disposal wellwell. The wells will notthen be drilled since it is no longer needed.placed on production. Prepaid costs for the period were $233,897.

The Company participated with its 10.5% interest in the drilling of an exploratory well and a salt water disposal well on a Seminole County, Oklahoma prospect. Surface facility construction and completion operations will start in November 2014. Prepaid drilling costs for the period were $200,808.

The Company participated with 10.7% and 10.3% working interests in the drilling of two development wells and with a 10.3% working interest in an unsuccessful re-entry and washdown attempt on a Woods County, Oklahoma prospect. OneBoth of the wells waswere completed as a commercial oil and gas producer and a completion is in progress on the other.producers. The Company will participate with 7%11.1% and 10.3% interests in two additional development wells starting in November 2014. Capitalized costs for the period were $154,552,$154,056, including $81,325$4,159 in prepaid drilling costs. Costs expensed to dry hole costs for the re-entry were $13,862.

The Company participated with a fee mineral interest in the drilling of a step-out horizontal well in Beaver County, Oklahoma. The Company has a 5.1% interest in the well which was completed as a commercial oil and gas producer.

In February 2014, the Company purchased a 10% interest in 250 net acres of leasehold on a McClain County, Oklahoma prospect for $11,875. The Company participated in the drilling of an exploratory well. A completion is in progress.well that was completed as a marginal oil producer. Capitalized costs for the period were $49,354.$108,577.

In March 2014, the Company purchased a 14% interest in 1,705 net acres of leasehold and 70 square miles of 3-D seismic data on a Creek County, Oklahoma prospect for $684,376. Seismic interpretation and additional leasehold acquisition are in progress. Eight potential structures have been identified and additional leasehold acquisition is in progress. Two exploratory drillingwells will startbe drilled starting in the second half ofNovember 2014. Additional leasehold costs for the period were $24,946.$29,914.

In JulySeptember 2014, the Company agreed to purchasepurchased a 14% interest in 160 net acres of leasehold on a Creek County, Oklahoma prospect for $24,500. An exploratory well has been drilled and a completion is in progress. Capitalized costs for the period were $60,218, including $48,174 in prepaid drilling costs.

In September 2014, the Company purchased a 10.5% interest in 180 net acres of leasehold on a Seminole County, Oklahoma prospect for $9,734. An exploratory well will be drilled starting in SeptemberNovember 2014. Capitalized costs for the period were $34,506, including $27,605 in prepaid drilling costs.

Depreciation, Depletion, Amortization and Valuation Provision (DD&A). DD&A increased $173,833 (10%) to $1,970,126In October 2014, the Company purchased a 10.5% interest in 2014 from $1,796,293a leasehold position on a Cowley County, Kansas prospect for $33,495. An exploratory well will be drilled starting in 2013. The increase was due to an increase of approximately $100,000 in current year depreciation expense on oil and gas properties and lease impairments of approximately $74,000.November 2014.

Other Income / (Loss), Net. This line item increased $33,430 (21%decreased $142,881 (51%) to $195,799$135,744 in 2014 from $162,369 in 2013. See Note 2 to the accompanying financial statements for the analysis of the various components of this line item. Components with significant changes are discussed in the following paragraphs.

Losses on trading securities in 2014 were $(5,983) as compared to gains of $79,794 in 2013, a decrease of $85,777. In 2014, the Company had realized gains of $18,779 and unrealized losses of $(24,762) from adjusting the securities to estimated fair market value. In 2013, the Company had realized losses of $(4,032) and unrealized gains of $83,826.

Other income increased $107,878 to $141,516 in 2014 from $33,638 in 2013. Most of the increase was due to $130,701 of class action lawsuit settlements in 2014 with no similar amounts in 2013. This increase was offset by a $23,000 decrease in other investment income to $10,000 in 2014 from $33,000 in 2013.

Provision for Income Taxes. The provision for income taxes increased $160,666 (13%) to $1,422,642 in 2014 from $1,261,976 in 2013. The increase was due to the higher income before income taxes of $710,220 (15%) to $5,468,854 in 2014 from $4,758,634 in 2013. Of the 2014 income tax provision, the estimated current tax expense was $1,623,195 and the estimated deferred tax benefit was $(200,553). Of the 2013 income tax provision, the current and deferred tax expenses were $556,334 and $705,642, respectively. See Note 4 to the accompanying financial statements for additional information on income taxes.

Material Changes in Results of Operations Three Months Ended June 30, 2014, Compared with Three Months Ended June30, 2013.

Net income decreased $182,138 (8%) to $2,071,509 in 2014 from $2,253,647 in 2013. The material changes in the results of operations, which caused the decrease in net income, are discussed below.

Operating Revenues. Revenues from oil and gas sales increased $147,568 (3%) to $5,103,967 in 2014 from $4,956,399 in 2013. The increase was the net result of a decrease in oil sales of $188,890 (5%) to $3,351,947; an increase in gas sales of $269,178 (20%) to $1,625,050; and an increase in sales of miscellaneous products of $67,280 to $126,970.

The $188,890 decrease in oil sales was the result of a decrease in the volume of oil sold of 5,460 Bbls to 35,021 Bbls, for a negative volume variance of $477,586, and an increase in the average price received of $8.24 per Bbl to $95.71, for a positive price variance of $288,696.

The $269,178 increase in gas sales was the result of an increase in the volume of gas sold of 11,532 MCF, for a positive volume variance of $45,897, and an increase in the average price of $0.63 per MCF to $4.61, for a positive price variance of $223,281.

Other operating revenues increased $278,988 (206%) to $414,592 in 2014 from $135,604 in 2013. This increase was due to an increase in lease bonuses for minerals in various Oklahoma and Texas Counties of $278,988 to $413,952 in 2014 from $134,964 in 2013. Coal royalties of $640 were received in 2014 and 2013.

Production Expense. Production expense increased $135,956 (20%) to $817,889 in 2014 from $681,933 in 2013. Lease operating expense and transportation and compression expense increased $99,225 to $609,877 in 2014 from $510,652 in 2013. Production taxes increased $36,731 to $208,012 in 2014 from $171,281 in 2013.

Other Income, Net. This line item increased $103,353 (96%) to $211,357 in 2014 from $108,004$278,625 in 2013. See Note 2 to the accompanying financial statements for an analysis of the components of other income, net. Components with significant changes are discussed in the following paragraphs.this item.

Other income increased $103,167 to $133,586Trading securities losses in 2014 were $(78,701) as compared to gains of $179,967 in 2013, a decrease of $258,668. In 2014, the Company had unrealized losses of $(109,604) from $30,419 in 2013. Mostadjusting securities, held at September 30, to estimated fair market value and net realized trading gains of $30,903. In 2013, the increase was due to $123,186Company had unrealized gains of class action lawsuit settlements in 2014 with no similar amounts in 2013. This increase was offset by a $20,000 decrease in other investment income to $10,000 in 2014 from $30,000 in 2013.$140,089 and net realized trading gains of $39,878.

Provision for Income Taxes. ProvisionThe provision for income taxes decreased $133,776 (15%increased $419,379 (24%) to $744,695$2,170,164 in 2014 from $878,471$1,750,785 in 2013. This increase was due primarily to the $1,431,451 (21%) increase in pretax income to $8,324,305 in 2014 from $6,892,854 in 2013. Of the 2014 income tax provision, the estimated current tax expense was $1,962,074 and the estimated deferred tax expense was $208,090. Of the 2013 income tax provision, the estimated current and deferred expenses were $1,207,228 and $543,557, respectively. See Note 4 to the accompanying financial statements for a discussion of the provision for income taxes.

Material Changes in Results of Operations Three Months Ended September 30, 2014, Compared with Three Months Ended September30, 2013.

Net income increased $462,517 (28%) to $2,107,928 in 2014 from $1,645,411 in 2013. The significant changes in the statements of income are discussed below.

Operating Revenues. Revenues from oil and gas sales decreased $37,201 (1%) to $4,642,249 in 2014 from $4,679,450 in 2013. The decrease was the net result of an increase in gas sales of $369,558 (32%) to $1,540,570; a decrease in oil sales of $413,456 (12%) to $3,005,618; and an increase in miscellaneous oil and gas product sales of $6,697 to $96,061.

The increase in gas sales was the result of an increase in the average price of $0.73 per MCF to $4.24, for a positive price variance of $264,981, and an increase in the volume of gas sold of 29,794 MCF to 363,441 MCF, for a positive volume variance of $104,577. See the “Results of Operations” section above for the nine months ended September 30, 2014 for additional discussion of gas sales variances.

The decrease in oil sales was the result of a decrease in the average price received of $7.85 per Bbl to $90.96, for a negative price variance of $259,510, and a decrease in the volume of oil sold of 1,558 Bbls to 33,043 Bbls, for a negative volume variance of $153,946. See the “Results of Operations” section above for the nine months ended September 30, 2014 for additional discussion of the oil sales variances.

Other operating revenues increased $666,542 to $682,558 for 2014, entirely due to an increase in lease bonuses.

Operating Costs and Expenses. Operating costs and expenses decreased $268,200 (10%) to $2,409,302 in 2014 from $2,677,502 in 2013. The decrease was the net result of an increase in production costs of $65,526; a decline in exploration costs charged to expense of $57,436; a decrease in depreciation, depletion, amortization and valuation provisions (DD&A) of $293,079; and an increase in general administrative and other expense (G&A) of $16,789. The significant changes in these line items are discussed below.

Production Costs. Production costs increased $65,526 (9%) to $791,436 in 2014 from $725,910 in 2013. Most of the increase is due to higher lease operating expenses for 2014 versus 2013, related primarily to the new wells that first produced after September 30, 2013. For more information about these changes, see the production costs discussion in the “Results of Operations” section above for the nine months ended September 30, 2014.

Exploration Costs. Exploration costs charged to operations decreased $57,436 (109%) to $(4,572) in 2014 from $52,864 in 2013 as a result of lower dry hole costs. See the exploration costs discussion in the “Results of Operations” section above for the nine months ended September 30, 2014.

Depreciation, Depletion, Amortization and Valuation Provisions (DD&A). DD&A decreased $293,079 (19%) to $1,254,193 in 2014 from $1,547,272 in 2013. The primary reason for the decrease was an impairment loss of $500,000 charged to operations in the quarter ending September 30, 2013 with no similar loss in 2014.

Other Income / (Loss), Net. See Note 2 to the accompanying financial statements for an analysis of the components of other income / (loss), net. In 2014, this line item decreased $176,311 to loss of $(60,055) from $116,256 in 2013.

Trading securities losses in 2014 were $(72,718) compared to gains of $100,173 in 2013. The gains and losses were primarily unrealized.

Provision for Income Taxes. The provision for income taxes increased $258,713 (53%) to $747,522 in 2014 from $488,809 in 2013 due to the $721,230 increase in pretax income in 2014 from 2013. See discussions above in “Item 2.”the “Results of Operations” section and Note 4 to the accompanying financial statements for a discussionadditional explanation of the changes in the provision for income taxes.

There were no additional material changes between the quarters, which were not covered in the discussion in “Item 2.”the “Results of Operations” section above for the sixnine months ended JuneSeptember 30, 2014.

Off-Balance Sheet ArrangementArrangements

The Company’s off-balance sheet arrangement relates to Broadway Sixty-Eight, Ltd., an Oklahoma limited partnership. The Company does not have actual or effective control of this entity. Management of this entity could at any time make decisions in its own best interest, which could materially affect the Company’s net income or the value of the Company’s investment.

For more information about this entity, see Note 3 to the accompanying financial statements.

Not applicable.

As defined in Rule 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934 (the “Exchange Act”"Exchange Act"), the term “disclosure controls and procedures” means controls and other procedures of an issuer that are designed to ensure that information required to be disclosed by the issuer in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’sSEC's rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Exchange Act is accumulated and communicated to the issuer’sissuer's management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate, to allow timely decisions regarding required disclosure.

The Company’s Principal Executive Officer and Principal Financial Officer evaluated the effectiveness of the Company’s disclosure controls and procedures. Based on this evaluation, they concluded that the Company’s disclosure controls and procedures were effective as of JuneSeptember 30, 2014.

Internal Control over Financial Reporting

As defined in Rule 13a-15(f) and 15d-15(f) of the Exchange Act, the term “internal"internal control over financial reporting”reporting" means a process designed by, or under the supervision of, the issuer’sissuer's principal executive and principal financial officers, or persons performing similar functions, and effected by the issuer’sissuer's board of directors, management and other personnel, 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 principles and includes those policies and procedures that:

The Company’sCompany's management is responsible for establishing and maintaining adequate internal control over financial reporting for the Company. There were no changes in the Company’s internal control over financial reporting during the quarter ended JuneSeptember 30, 2014 that have materially affected, or are reasonably likely to materially affect, the Company’sCompany's internal control over financial reporting.

PART II – OTHER INFORMATION

During the quarter ended JuneSeptember 30, 2014, the Company did not have any material legal proceedings brought against it or its properties.

Not applicable.

¹The Company has no formal equity security purchase program or plan. The Company acts as its own transfer agent, and most purchases result from requests made by stockholders receiving small odd lot share quantities as the result of probate transfers.

None.

Not applicable.

None.

The following documents are exhibits to this Form 10-Q. Each document marked by an asterisk is filed electronically herewith.

* Filed electronically herewith.

SIGNATURES

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