RESERVE PETROLEUM CO - Annual Report: 2015 (Form 10-K)

 UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

(Mark One)

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

For the Fiscal Year Ended December 31, 2015

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

Commission File Number 0-8157

THE RESERVE PETROLEUM COMPANY

(Exact Name of Registrant as Specified in Its Charter)

Securities registered under Section 12(b) of the Exchange Act:  NONE

Securities registered under Section 12(g) of the Exchange Act:

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

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.

Yes     ☐     No     ☑

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

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 June 30, 2015 (the last business day of the registrant’s most recently completed second fiscal quarter), the aggregate market value of the voting and non-voting common stock of the registrant held by non-affiliates of the registrant was $35,184,758, as computed by reference to the last reported sale which was on June 29, 2015.

As of March 24, 2016, there were 158,188 shares of the registrant’s common stock outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the definitive proxy statement (the “Proxy Statement”) relating to the registrant’s Annual Meeting of Shareholders to be held on May 24, 2016, which will be filed within 120 days of the end of the registrant’s year ended December 31, 2015, are incorporated by reference into Part III of this Form 10-K to the extent described therein.

TABLE OF CONTENTS

Forward-Looking Statements

This Report on Form 10-K contains forward-looking statements. Actual events and/or future results of operations may differ materially from those contemplated by such forward-looking statements. See Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” for a summation of some of the risks and uncertainties inherent in forward-looking statements. Readers should consider the risks and uncertainties described in connection with any forward-looking statements that may be made in this Form 10-K. Readers should carefully review this Form 10-K in its entirety including, but not limited to, the Company's financial statements and the notes thereto and the risks and uncertainties described herein. Forward-looking statements contained in this Form 10-K speak only as of the date of this Form 10-K. The Company does not undertake to update its forward-looking statements.

PART I

Item 1.     Business

Overview

The Reserve Petroleum Company (the “Company”, “we”, “our” or “us”) is engaged principally in managing its owned mineral properties and the exploration for and the development of oil and natural gas properties. Other business segments are not significant factors in our operations. The Company is a corporation organized under the laws of the State of Delaware in 1931.

Oil and Natural Gas Properties

For a summary of certain data relating to the Company’s oil and gas properties including production, undeveloped acreage, producing and dry wells drilled and recent activity, see Item 2, “Properties.” For a discussion and analysis of current and prior years’ revenue and related costs of oil and gas operations and a discussion of liquidity and capital resource requirements, see Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Owned Mineral Property Management

The Company owns non-producing mineral interests in 256,362 gross acres equivalent to 88,314 net acres. These mineral interests are located in nine different states in the north and south central United States. A total of 81,181 (92%) net acres are located in the states of Arkansas, Kansas, Oklahoma, South Dakota and Texas, the areas of concentration for the Company in our exploration and development programs.

The Company has several options relating to the exploration and/or development of our owned mineral interests. Management continually reviews various industry reports and other sources for activity (leasing, drilling, significant discoveries, etc.) in areas where the Company has mineral ownership. Based on our analysis of any activity and assessment of the potential risk relative to the particular area, management may negotiate a lease or farmout agreement and accept a royalty interest, or we may choose to participate as a working interest owner and pay our proportionate share of any exploration or development drilling costs.

A substantial amount of the Company’s oil and gas revenue has resulted from our owned mineral property management. In 2015, $1,969,058 (26%) of oil and gas sales was from royalty interests versus $4,715,113 (25%) in 2014. As a result of our mineral ownership, the Company had royalty interests in 17 gross (0.21 net) wells, which were drilled and completed as producing wells in 2015. This resulted in an average royalty interest of about 1.3% for these 17 new wells. The Company has very little control over the timing or extent of the operations conducted on our royalty interest properties. See the following paragraphs for a discussion of mineral interests in which the Company chooses to participate as a working interest owner.

Development Program

Development drilling by the Company is usually initiated in one of three ways. The Company may participate as a working interest owner with a third party operator in the development of non-producing mineral interests, which it owns; with a joint interest operator, we may participate in drilling additional wells on our producing leaseholds; or if our exploration program, discussed below, results in a successful exploratory well, we may participate in the drilling of additional wells on the exploratory prospect. In 2015, the Company participated in the drilling of 11 development wells with 6 wells (0.68 net), including the 5 wells in progress at the end of 2014, completed as producers, and 5 wells (0.52 net) in progress at the time of this Form 10-K.

Exploration Program

The Company’s exploration program is normally conducted by purchasing interests in prospects developed by independent third parties; participating in third party exploration of Company-owned non-producing minerals; developing our own exploratory prospects; or a combination of the above.

The Company normally acquires interests in exploratory prospects from someone in the industry with whom management has conducted business in the past and/or if management has confidence in the quality of the geological and geophysical information presented for evaluation by Company personnel. If evaluation indicates the prospect is within our risk limits, we may negotiate to acquire an interest in the prospect and participate in a non-operating capacity.

The Company develops exploratory drilling prospects by identification of an area of interest, development of geological and geophysical information and purchase of leaseholds in the area. The Company may then attempt to sell an interest in the prospect to one or more companies in the petroleum industry with one of the purchasing companies functioning as operator. In 2015, we participated in the drilling of 12 exploratory wells with 5 wells (0.61 net), including 3 wells in progress at the end of 2014, completed as producers; 7 wells (0.78 net) completed as dry holes.

For a summation of exploratory and development wells drilled in 2015 or planned for in 2016, see Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” subheading “Update of Oil and Gas Exploration and Development Activity from December 31, 2014.”

Customers

In 2015, the Company had one customer whose total purchases were greater than 10% of revenues from oil and gas sales. Redland Resources, Inc. purchases were $2,035,400 or 27% of total oil and gas sales. The Company sells most of its oil and gas under short-term sales contracts that are based on the spot market price. A minor amount of oil and gas sales are made under fixed price contracts having terms of more than one year.

Competition

The oil and gas industry is highly competitive in all of its phases. There are numerous circumstances within the industry and related market place that are out of the Company’s control such as cost and availability of alternative fuels, the level of consumer demand, the extent of other domestic production of oil and gas, the price and extent of importation of foreign oil and gas, the cost of and proximity of pipelines and other transportation facilities, the cost and availability of drilling rigs, regulation by state and federal authorities, and the cost of complying with applicable environmental regulations.

The Company does not operate any of the wells in which we have an interest; rather, we partner with companies that have the resources, staff, and experience to operate wells both in the drilling and production phases. The Company uses its strong financial base and its mineral and leasehold acreage ownership, along with its own geologic and economic evaluations, to participate in drilling operations with these companies. This methodology allows us to participate in exploration and development activities we could not undertake on our own due to financial and personnel limits and allows us to maintain low overhead costs.

Regulation

The Company’s operations are affected in varying degrees by political developments and federal and state laws and regulations. Although released from federal price controls, interstate sales of natural gas are subject to regulation by the Federal Energy Regulatory Commission (FERC). Oil and gas operations are affected by environmental laws and other laws relating to the petroleum industry, and both are affected by constantly changing administrative regulations. Rates of production of oil and gas have, for many years, been subject to a variety of conservation laws and regulations, and the petroleum industry is frequently affected by changes in the federal tax laws.

Generally, the respective state regulatory agencies supervise various aspects of oil and gas operations within their states and the transportation of oil and gas sold intrastate.

Environmental Protection and Climate Change

The operation of the various producing properties, in which the Company has an interest, is subject to federal, state, and local provisions regulating discharge of materials into the environment, the storage of oil and gas products, and the contamination of subsurface formations. The Company’s lease operations and exploratory activity have been and will continue to be affected by existing regulations in future periods. However, the known effect to date has not been material as to capital expenditures, earnings, or industry competitive position. Environmental compliance expenditures produce no increase in productive capacity or revenue and require more of management’s time and attention at a cost which cannot be estimated with any assurance of certainty.

In 2009, the EPA officially published its findings that greenhouse gas emissions present an endangerment to human health and the environment. According to the EPA, these emissions are contributing to global warming and climate change. These findings allowed the EPA to adopt and implement regulations in recent years to restrict these emissions under existing provisions of the Federal Clean Air Act.

The Company may be, directly and indirectly, subject to the effects of climate change and may, directly or indirectly, be affected by government laws and regulations related to climate change. We cannot predict with any degree of certainty what effect, if any, climate change and government laws and regulations related to climate change will have on the Company and our business, whether directly or indirectly. While we believe that it is difficult to assess the timing and effect of climate change and pending legislation and regulation related to climate change on our business, we believe that those laws and regulations may affect, directly or indirectly, (i) the costs associated with drilling and production operations in which we participate; (ii) the demand for oil and natural gas; (iii) insurance premiums, deductibles and the availability of coverage; and (iv) the cost of utilities paid by the Company. In addition, climate change may increase the likelihood of property damage and the disruption of operations of wells in which we participate. As a result, our financial condition could be negatively impacted, but we are unable to determine at this time whether that impact would be material.

Other Business

See Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” subheading “Equity Investments” and Item 8, Notes 2 and 7 to the accompanying financial statements for a discussion of other business including guarantees.

Employees

At December 31, 2015, the Company had nine employees, including officers. See the Proxy Statement for additional information. During 2015, all of our employees devoted a portion of their time to duties with affiliated companies, and we were reimbursed for the affiliates’ share of compensation directly from those companies. See Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” subheading “Certain Relationships and Related Transactions” and Item 8, Note 12 to the accompanying financial statements for additional information.

Not applicable.

Not applicable 

The Company’s principal properties are oil and natural gas properties. We have interests in approximately 900 producing properties with 39% of them being working interest properties and the remaining 61% being royalty interest properties. About 80% of all properties are located in Oklahoma and Texas and account for approximately 73% of our annual oil and gas sales. About 16% of the properties are located in Arkansas, Kansas and South Dakota and account for approximately 25% of our annual oil and gas sales. The remaining 4% of these properties are located in Colorado and Montana and account for less than 2% of our annual oil and gas sales. No individual property provides more than 7% of our annual oil and gas sales. See discussion of revenues from Robertson County, Texas, royalty interest properties in Item 7, “Operating Revenues” for additional information about significant properties.

OIL AND NATURAL GAS OPERATIONS

Oil and Gas Reserves

Reference is made to the Unaudited Supplemental Financial Information beginning on Page 30 for working interest reserve quantity information.

Since January 1, 2015, the Company has not filed any reports with any federal authority or agency, which included estimates of total proved net oil or gas reserves, except for its 2014 Annual Report on Form 10-K and federal income tax return for the year ended December 31, 2014. Those reserve estimates were identical.

Production

The average sales price of oil and gas production for the Company’s royalty and working interests, as well as the average working interest production cost (lifting cost) per equivalent thousand cubic feet (MCF) of gas, are presented in the table below for the years ended December 31, 2015, 2014 and 2013. Equivalent MCF was calculated using approximate relative energy content.

At December 31, 2015, the Company had working interests in 214 gross (26.45 net) wells producing primarily gas and 229 gross (22.27 net) wells producing primarily oil. These interests were in 85,249 gross (9,744 net) producing acres. These wells include 50 gross (1.29 net) wells associated with secondary recovery projects.

Undeveloped Acreage

The Company’s undeveloped acreage consists of non-producing mineral interests and undeveloped leaseholds. The following table summarizes the Company’s gross and net acres in each at December 31, 2015.

Net Productive and Dry Wells Drilled

The following table summarizes the net wells drilled in which the Company had a working interest for the years ended December 31, 2013 and thereafter, as to net productive and dry exploratory wells drilled and net productive and dry development wells drilled. Net exploratory and development totals for 2015 include the 9 wells still drilling at the end of 2014. As indicated in the “Development Program” on Page 3 and “Exploration Program” on Page 4, 5 development wells were still in process at the time of this Form 10-K.

Recent Activities

See Item 7, under the subheading “Update of Oil and Gas Exploration and Development Activity from December 31, 2014” for a summary of recent activities related to oil and natural gas operations.

There are no material legal proceedings pending affecting the Company or any of its properties.

Not applicable.

PART II

The Company’s stock is dually traded in the Pink Sheet Electronic Quotation Service and the OTC Bulletin Board under the symbol “RSRV.” The following high and low bid information was quoted on the Pink Sheets OTC Market Report. Prices reflect inter-dealer prices without retail markup, markdown, or commission and may not reflect actual transactions.

There was limited public trading in the Company’s common stock in 2015 and 2014. There were 10 brokered trades appearing in the Company’s transfer ledger for 2015 and 44 in 2014.

At March 18, 2016, the Company had approximately 1,760 record holders of its common stock. The Company paid dividends on its common stock in the amount of $10.00 per share in the second quarter of 2015 and $20.00 per share in the second quarter of 2014. See the “Financing Activities” section of Item 7 below for more information about dividends paid. Management will review the amount of the annual dividend to be paid in 2016, if any, with the Board of Directors for its approval.

ISSUER PURCHASES OF EQUITY SECURITIES

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 shareholders receiving small, odd lot share quantities as the result of probate transfers.

Not applicable.

Please refer to the financial statements and related notes in Item 8 of this Form 10-K to supplement this discussion and analysis.

Forward-Looking Statements

In addition to historical information, from time to time the Company may publish 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 provide the reader with management’s current expectations of future events. They include statements relating to such matters as anticipated financial performance, business prospects such as drilling of oil and gas wells, technological development, and similar matters.

Although management believes that the expectations reflected in forward-looking statements are based on reasonable assumptions, a variety of factors could cause the Company’s actual results and experience to differ materially from the anticipated results or other expectations expressed in the Company’s forward-looking statements. The risks and uncertainties that may affect the operations, performance, development, and results of our business include, but are not limited to, the following:

The Company does not undertake any obligation to publicly revise forward-looking statements to reflect events or circumstances that arise after the filing date of this Form 10-K. Readers should carefully review the information described in other documents the Company files from time to time with the Securities and Exchange Commission, including the Quarterly Reports on Form 10-Q to be filed by the Company in 2016 and any Current Reports on Form 8-K filed by the Company.

Critical Accounting Estimates

CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

The Company is affiliated by common management and ownership with Mesquite Minerals, Inc. (Mesquite), Mid-American Oil Company (Mid-American) and Lochbuie Limited Liability Company (LLTD). The Company also owns interests in certain producing and non-producing oil and gas properties as tenants in common with Mesquite, Mid-American and LLTD.

Robert T. McLain and Jerry Crow, directors of the Company, are directors of Mesquite and Mid-American. Kyle McLain, Cameron R. McLain and John McLain are brothers and directors of the Company. Kyle McLain and Cameron McLain each own more than 5% of the common stock of the Company and are officers. Kyle McLain and Cameron McLain are officers and directors of Mesquite and Mid-American. Robert T. McLain owns an approximate 33% interest in LLTD. Robert T. McLain and John McLain are not employees of any of the above entities and devote only a small amount of time conducting their business.

The above named officers, directors, and employees as a group beneficially own approximately 27% of the common stock of the Company, approximately 15% of the common stock of Mesquite, and approximately 5% of the common stock of Mid-American. These three corporations each, have only one class of stock outstanding. See Item 8, Note 12 to the accompanying financial statements for additional disclosures regarding these relationships.

EQUITY INVESTMENTS

The Company had a 33% partnership interest in Broadway Sixty-Eight, Ltd. (the “Partnership”) in 2014 and 2015, which it accounted for on the equity method. In using the equity method, the Company records the original investment in an entity as an asset and adjusts the asset balance for the Company’s share of any income or loss, as well as any additional contributions to or distributions from the entity. The Company does not have actual or effective control of the Partnership. The management of the Partnership could, at any time, make decisions in their own best interests that could affect the Company’s net income or the value of the Company’s investment.

The Partnership has an indemnity agreement under which the Company is contingently liable. See Item 8, Note 7 to the accompanying financial statements for related disclosures and additional information regarding Broadway Sixty-Eight, Ltd.

The Company’s Equity Investments also include a 47% ownership in Grand Woods Development, LLC (the “LLC”) an Oklahoma limited liability company acquired in November 2015. The LLC owns approximately 26.3 acres of undeveloped real estate in northeast Oklahoma City, and has entered into a contract to sell all of the real estate with a developer that is scheduled to close by March 31, 2016. The Company has guaranteed a loan for which the proceeds were used to purchase a portion of the undeveloped real estate acreage.

LIQUIDITY AND CAPITAL RESOURCES

To supplement the following discussion, please refer to the Balance Sheets and the Statements of Cash Flows included in this Form 10-K.

In 2015, as in prior years, the Company funded its business activity through the use of internal sources of capital. For the most part, these internal sources are cash flows from operations, cash, cash equivalents and available-for-sale securities. When cash flows from operating activities are in excess of those needed for other business activities, the remaining balance is used to increase cash, cash equivalents and/or available-for-sale securities. When cash flows from operating activities are not adequate to fund other business activities, withdrawals are made from cash, cash equivalents and/or available-for-sale securities. Cash equivalents are highly liquid debt instruments purchased with a maturity of three months or less. All of the available-for-sale securities are U.S. Treasury Bills.

In 2015, net cash provided by operating activities was $5,425,939. Sales (including lease bonuses), net of production costs, general and administrative costs and income taxes paid were $4,926,433, which accounted for 91% of net cash provided by operations. The remaining components provided 10% of cash flow. In 2015, net cash applied to investing activities was $5,017,556. In 2015, dividend payments and treasury stock purchases totaled $1,674,726 and accounted for all of the cash applied to financing activities..

Other than cash and cash equivalents, other significant changes in working capital include the following:

Trading securities decreased $34,752 (8%) to $410,724 in 2015 from $445,476 in 2014. The net decrease is due to $67,643 in unrealized losses, which represent the change in the fair value of the securities from their original cost, offset by $32,891 of 2015 income.

Refundable income taxes increased $333,659 (216%) to $488,052 in 2015 from $154,393 in 2014.

Receivables decreased $1,497,488 (70%) to $644,868 in 2015 from $2,142,356 in 2014. The decrease was due primarily to the use of lower product prices for oil sales accrual estimates for year-end 2015 compared to 2014. Additional information about oil sales for 2015 is included in the “Results of Operations” section that follows.

Accounts payable decreased $593,362 (72%) to $225,648 in 2015 from $819,010 in 2014. This decrease was primarily due to decreased drilling activity due to low oil and gas prices.

Deferred income taxes and other accrued liabilities decreased $224,741 (85%) to $38,493 in 2015 from $263,234 in 2014.

The following is a discussion of material changes in cash flow by activity between the years ended December 31, 2015 and 2014. Also, see the discussion of changes in operating results under “Results of Operations” below in this Item 7.

Operating Activities

As noted above, net cash flows provided by operating activities in 2015 were $5,425,939, which, when compared to the $14,591,253 provided in 2014, represents a net decrease of $9,165,314 or 63%. The decrease was mostly due to a decrease in oil and gas sales cash flows of $10,235,921, decreased lease bonus cash flows of $1,283,578 and $254,595 decrease in cash distributions from our equity investment in Broadway Sixty-Eight, Ltd. These were offset by a decrease in production costs of $729,782, taxes of $1,586,371 and an increase of $391,290 received from an insurance policy. Additional discussion of the more significant items follows.

Discussion of Selected Material Line Items Resulting in a Decrease in Cash Flows. The $10,235,921 (53%) decrease in cash received from oil and gas sales to $9,139,958 in 2015 from $19,375,879 in 2014 was the result of a decrease in both oil and gas sales volumes and prices. See “Results of Operations” below for a price/volume analysis and the related discussion of oil and gas sales.

Cash received for lease bonuses decreased $1,283,578 (61%) to $809,980 in 2015 from $2,093,558 in 2014.

The 2015 cash distribution from our equity investment in Broadway Sixty-Eight, Ltd., of $82,500 was primarily for our share of operating profits. The 2014 cash distribution of $337,095 included our share of operating profits plus the profits from the construction and sale of several small office buildings on some land adjacent to our current office building. See Item 8, Note 7 to the accompanying financial statements for additional information regarding Broadway Sixty-Eight, Ltd.

Discussion of Selected Material Line Items Resulting in an Increase in Cash Flows. Cash paid for production costs decreased $729,782 (22%) to $2,664,013 in 2015 from $3,393,795 in 2014. This decrease was due to lower lease operating expense of $261,143 and lower production taxes of $468,639 as a result of the decrease in oil and gas sales discussed above.

Cash paid for estimated income taxes decreased $1,586,371 (69%) to $720,544 in 2015 from $2,306,915 in 2014. The lower payments were mostly due to lower net income and current taxable income in 2015.

Investing Activities

Net cash applied to investing activities decreased $1,869,875 (27%) to $5,017,556 in 2015 from $6,887,431 in 2014. This $1,869,875 decrease was due primarily to a $4,207,890 decrease in cash applied to exploration and development expenditures. See the “Exploration and Development Costs” section in the “Results of Operations” section below for more information. This decline in cash applied to exploration and development expenditures and other investments was partially offset by the $1,986,758 purchase of additional available-for-sale securities as a result of the rising short-term interest rates and a $329,815 increase in purchases of equity and other investments. The 2015 purchases include a $656,000 equity investment in Grand Woods Development, LLC. See Item 8, Note 7 to the accompanying financial statements for additional information regarding Grand Woods Development, LLC.

Financing Activities

Cash applied to financing activities decreased $1,590,044 (49%) to 1,674,726 in 2015 from $3,264,770 in 2014. Cash applied to financing activities consist of cash dividends on common stock and cash used for the purchase of treasury stock. In 2015, cash dividends paid on common stock amounted to $1,627,930 as compared to $3,097,246 in 2014. Dividends of $10.00 per share were paid in 2015 and $20.00 per share in 2014. Cash applied to purchase treasury stock decreased $120,728 to $46,796 in 2015 from $167,524 in 2014.

Forward-Looking Summary

The Company’s latest estimate of business to be done in 2016 and beyond indicates the projected activity can be funded from cash flow from operations and other internal sources, including net working capital. The Company is engaged in exploratory drilling. If this drilling is successful, substantial development drilling may result. Also, should other exploration projects which fit the Company’s risk parameters become available or other investment opportunities become known, capital requirements may be more than the Company has available. If so, external sources of financing could be required.

RESULTS OF OPERATIONS

As disclosed in the Statements of Operations in Item 8 of this Form 10-K, in 2015 the Company had a net loss of ($1,885,332) as compared to net income of $6,762,875 in 2014. Net income/(loss) per share, basic and diluted, was ($11.89) in 2015, a decrease of $54.44 per share from $42.55 in 2014. Material line item changes in the Statements of Operations will be discussed in the following paragraphs.

Operating Revenues

Operating revenues decreased $12,716,826 (60%) to $8,450,986 in 2015 from $21,167,812 in 2014. Oil and gas sales decreased $11,433,248 (60%) to $7,641,006 in 2015 from $19,074,254 in 2014. Lease bonuses and other revenues decreased $1,283,578 (61%) to $809,980 in 2015 from $2,093,558 in 2014. This decrease was the indirect result of the declining oil and gas prices. The decrease in oil and gas sales is discussed in the following paragraphs.

The $11,433,248 decrease in oil and gas sales was the net result of a $3,643,150 decrease in gas sales, a $7,347,723 decrease in oil sales and a $442,375 decrease in miscellaneous oil and gas product sales. The following price and volume analysis is presented to explain the changes in oil and gas sales from 2015 to 2014. Miscellaneous oil and gas product sales of $179,378 in 2015 and $621,753 in 2014 are not included in the analysis.

The $3,643,150 (56%) decrease in natural gas sales to $2,810,121 in 2015 from $6,453,271 in 2014 was the result of a decrease in both gas sales volumes and the average price received per thousand cubic feet (MCF). The average price per MCF of natural gas sales decreased $1.88 per MCF to $2.51 in 2015 from $4.39 per MCF in 2014, resulting in a negative gas price variance of $2,100,628. A negative volume variance of $1,542,522 was the result of a decrease in natural gas volumes sold of 351,372 MCF to 1,119,192 MCF in 2015 from 1,470,564 MCF in 2014. The decrease in the volume of gas production was the net result of new 2015 production of about 34,000 MCF, offset by a decline of about 385,000 MCF in production from previous wells. About 90,000 MCF (23%) of this decline is from working interest wells in Van Buren County, Arkansas. As disclosed in Supplemental Schedule 1 of the Unaudited Supplemental Financial Information included in Item 8 below, working interests in natural gas extensions and discoveries were adequate to replace working interest reserves produced in 2014 but not in 2015.

The gas production for 2014 and 2015 includes production from about 100 royalty interest properties drilled by various operators in Robertson County, Texas. These properties accounted for approximately 304,000 MCF and $1,258,000 of the 2014 gas sales and approximately 244,000 MCF and $621,000 of the 2015 gas sales. These properties accounted for about 20% of the Company’s gas revenues in both years. The Company has no control over the timing of future drilling on the acreage in which we hold mineral interests.

The $7,347,723 (61%) decrease in crude oil sales to $4,651,507 in 2015 from $11,999,230 in 2014 was the result of a decrease in both the average price per barrel (Bbl) and the oil sales volumes. The average price received per Bbl of oil decreased $43.21 to $44.00 in 2015 from $87.21 in 2014, resulting in a negative oil price variance of $4,568,388. A decline in oil sales volumes of 31,869 Bbls to 105,716 Bbls in 2015 from 137,585 Bbls in 2014 resulted in a negative volume variance of $2,779,335. The decrease in the oil volume production was the net result of new 2015 production of about 10,000 Bbls, offset by a 41,900 Bbl decline in production from previous wells. Of the new 2015 production, approximately 3,500 Bbls (35%) was from new working interest wells in Woods County, Oklahoma. As disclosed in Supplemental Schedule 1 of the Unaudited Supplemental Financial Information included below in Item 8, working interests in oil extensions and discoveries were not adequate to replace working interest reserves produced in 2015 or 2014.

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.

Operating Costs and Expenses

Operating costs and expenses decreased $544,278 (4%) to $11,917,416 in 2015 from $12,461,694 in 2014, primarily due to a decrease in production and exploration expense. The material components of operating costs and expenses are discussed below.

Production Costs. Production costs decreased $776,768 (23%) to $2,601,044 in 2015 from $3,377,812 in 2014. The decrease was primarily the result of a $468,639 (60%) decrease in gross production tax to $310,921 in 2015 from $779,560 in 2014 and a decrease in lease operating expense of $215,374 (11%) to $1,788,733 in 2015 from $2,004,107 in 2014. Of the decrease in lease operating expense, $260,883 was the result of decreased expenses for existing wells offset by $45,509 of expenses for new wells. Gross production taxes are state taxes, which are calculated as a percentage of gross proceeds from the sale of products from each producing oil and gas property; therefore, they fluctuate with the change in the dollar amount of revenues from oil and gas sales.

Exploration and Development Costs. Under the successful efforts method of accounting used by the Company, geological and geophysical costs are expensed as incurred as are the costs of unsuccessful exploratory drilling. The costs of successful exploratory drilling and all development costs are capitalized. Total costs of exploration and development, excluding asset retirement obligations but inclusive of geological and geophysical costs, were $1,467,772 in 2015 and $6,350,095 in 2014. See Item 8, Note 8 to the accompanying financial statements for a breakdown of these costs. Exploration costs charged to operations were $584,705 in 2015 and $1,284,483 in 2014, inclusive of unsuccessful exploratory well costs of $374,066 in 2015 and $598,900 in 2014, and geological and geophysical costs of $210,639 in 2015 and $685,583 in 2014.

Update of Oil and Gas Exploration and Development Activity from December 31, 2014. For the year ended December 31, 2015, the Company participated in the drilling of 12 gross exploratory and 11 gross development working interest wells with working interests ranging from a high of 16% to a low of 8%. Of the 12 exploratory wells, 5 were completed as producing wells and 7 as dry holes. Of the 11 development wells, 6 were completed as producing wells and 5 were in progress. In management’s opinion, the exploratory drilling summarized above has produced some possible development drilling opportunities.

The following is a summary as of March 7, 2016, updating both exploration and development activity from December 31, 2014, for the period ended December 31, 2015.

The Company participated with its 16% working interest in the drilling of a development well on a Woods County, Oklahoma prospect. The well was completed as a commercial oil and gas producer. Capitalized costs for the period were $68,293.

The Company participated with an 8% working interest in the completion of a development well that was drilled in 2014 on a Woods County, Oklahoma prospect. The well is a commercial oil and gas producer.

The Company participated with 10.3% and 10.7% working interests in the drilling of two development wells on a Woods County, Oklahoma prospect. Completions are in progress on both wells. Capitalized costs for the period were $71,264.

The Company participated with its 10.5% working interest in the drilling of two exploratory wells on a Cimarron County, Oklahoma prospect. Both wells were completed as dry holes. No further drilling is planned on the prospect. Costs expensed to dry hole costs were $132,554. Leasehold impairment expense for the prospect was $120,675.

The Company participated with its 10.5% working interest in the completion of an exploratory well that was drilled in 2014 on a Logan County, Oklahoma prospect. The well is a marginal oil and gas producer. Capitalized costs for the period were $60,435.

The Company participated with its 10.5% working interest in the drilling of a development well on a Seminole County, Oklahoma prospect. The well has been completed and is being tested. The Company also participated in operations to plug back and repair a salt water disposal well that has been returned to service, and in the installation of submersible pumping equipment in another well that is now a commercial oil producer.

The Company participated with its 10.5% working interest in the drilling of three development wells on a Seminole County, Oklahoma prospect. One well has been completed and tested and appears to be noncommercial. Another has been completed and is being tested, and the third is awaiting the installation of pumping equipment. Capitalized costs for the period were $289,244.

The Company participated in the drilling of three exploratory wells on a Creek County, Oklahoma prospect. Two of these wells were completed as dry holes and the other as a marginal oil producer. Dry hole costs for the period were $56,052 and capitalized costs were $53,590.

The Company participated with its 8.4% interest in a 3-D seismic survey on a Thomas County, Kansas prospect. The Company also participated in the drilling of an exploratory well on the prospect that was completed as a dry hole, and in the acquisition of additional acreage. Additional 3-D seismic data has been acquired and is being processed. Costs expensed to dry hole costs were $29,259. Leasehold costs for the period were $15,023 and seismic costs were $19,783.

In April 2015, the Company purchased a 16% interest in 1,861 net acres of leasehold on a Chase County, Nebraska prospect for $40,191. The Company participated in the drilling of an exploratory well on the prospect that was completed as a commercial oil producer and in the drilling of a step-out well that is awaiting completion. Capitalized costs for the period were $147,309.

In July 2015, the Company purchased a 10.5% interest in 18,069.51 net acres of leasehold on a Thomas County, Kansas prospect for $218,189. A 3-D seismic survey of the prospect has been conducted and the data is being processed. After processing and analysis, decisions about exploratory drilling will be made. Seismic costs for the period were $106,718.

In October 2015, the Company purchased a 14% interest in 1,280 net acres of leasehold and a producing well on a Hansford County, Texas prospect for $108,385. The acreage has been unitized and will be developed for waterflooding. Development plans have been delayed by low oil prices, but drilling should commence sometime in 2016.

In November 2015, the Company purchased a 16% interest in 320 net acres of leasehold on two Kingman County, Kansas prospects for $5,120. The Company participated in the re-entry and washdown of an old dry hole on each prospect. Completion attempts on both wells were unsuccessful and both will be plugged. Dry hole costs for the period were $40,683.

In February 2016, the Company purchased a 16% interest in 12,252.36 net acres of leasehold on a Chase County, Nebraska prospect for $151,929 and paid $88,704 in seismic costs. A 3-D seismic survey of the prospect will be conducted starting in March 2016.

Depreciation, Depletion, Amortization and Valuation Provisions (DD&A). Major DD&A components are the provision for impairment of undeveloped leaseholds, provision for impairment of long-lived assets, depletion of producing leaseholds and depreciation of tangible and intangible lease and well costs. Undeveloped leaseholds are amortized over the life of the leasehold (most are 3 years) using a straight line method, except when the leasehold is impaired or condemned by drilling and/or geological interpretation of seismic data; if so, an adjustment to the provision is made at the time of impairment. The provision for impairment of undeveloped leaseholds was $329,871 in 2015 and $310,413 in 2014. Of the 2015 provision, $301,052 was due to the annual amortization of undeveloped leaseholds and $28,819 was due to specific leasehold impairments. The 2014 provision was due to the annual amortization of undeveloped leaseholds of $190,407 and specific leasehold impairments of $120,006.

As discussed in Item 8, Note 10 to the accompanying financial statements, accounting principles require the recognition of an impairment loss on long-lived assets used in operations when indicators of impairment are present. Impairment evaluation is a two-step process. The first step is to measure when the undiscounted cash flows estimated to be generated by those assets, determined on a well basis, is less than the assets’ carrying amounts. Those assets meeting the first criterion are adjusted to estimated fair value. Evaluation for impairment was performed in both 2015 and 2014. The 2015 impairment loss was $3,726,267 and the 2014 impairment loss was $1,928,548. The $1,797,719 increase in impairments in 2015 was mainly due to the decline in oil and natural gas prices.

The depletion and depreciation of oil and gas properties are computed by the units-of-production method. The amount expensed in any year will fluctuate with the change in estimated reserves of oil and gas, a change in the rate of production or a change in the basis of the assets. In 2014, approximately 17% of the working interest wells in which the Company participated were horizontal wells. In 2015, the Company did not participate in any horizontal working interest wells. A horizontal well may cost five to eight times as much as a vertically drilled well. In addition, horizontal wells’ initial production rates tend to be greater and their production decline rates are usually higher than in vertical wells. The larger investment in the costlier horizontal wells and the increased production rates result in an increase in depreciation expense. The provision for depletion and depreciation declined $854,022 (22%) to $3,003,193 in 2015 from $3,857,215 in 2014. This decrease is due to the reasons discussed above. The provision also includes $135,088 for 2015 and $90,151 for 2014 for the amortization of the Asset Retirement Costs. See Item 8, Note 2 to the accompanying financial statements for additional information regarding the Asset Retirement Obligation.

Other Income, Net. See Item 8, Note 11 to the accompanying financial statements for an analysis of the components of this line item for 2015 and 2014. Other income, net decreased $37,136 (35%) to $70,278 in 2015 from $107,414 in 2014. The line items responsible for this net decrease are described below.

Net realized and unrealized gain (loss) on trading securities increased $106,781 to a net loss of ($35,741) in 2015 from a net loss of ($142,522) in 2014. Realized gains or losses result when a trading security is sold. Unrealized gains or losses result from adjusting the Company’s carrying amount in trading securities owned at the reporting date to estimated fair value. In 2015, the Company had realized gains of $31,902 and unrealized losses of $67,643. In 2014, the Company had realized gains of $58,192 and unrealized losses of $200,714.

Income from investments increased $40,000 to $60,000 in 2015 from $20,000 in 2014.

Interest and other expenses increased $2,999 to $48,047 in 2015 from $45,048 in 2014. The increase was due primarily to a $2,929 increase in the accretion expense to $47,531 in 2015 from $44,602 in 2014.

Gains on asset sales decreased $51,202 to $68,487 in 2015 from $119,689. The gains in 2014 included a sale of approximately $99,000 for some non-producing leasehold that had been fully amortized. There were no similar sales in 2015.

Interest income decreased $3,824 to $13,353 in 2015 from $17,177 in 2014. This decrease was the net result of a decline in the average interest rate, partially offset by an increase in the average balance of cash equivalents and average balance of available-for-sale securities from which most of the interest income is derived. The average interest rate declined from 0.14% in 2014 to 0.11% in 2015. The average balance outstanding increased $9,082 to $11,850,477 in 2015 from $11,841,395 in 2014.

Class action settlements declined $125,585 to $5,593 in 2015 from $131,178 in 2014.

Provision for Income Taxes. See Item 8, Note 6 to the accompanying financial statements for an analysis of the various components of income taxes. In 2015, the Company had an estimated income tax benefit of $1,472,545 as the result of a current tax provision of $386,886, offset by a deferred tax benefit of $1,859,431. In 2014, the Company had an estimated provision for income taxes of $2,117,241 as the result of a current tax provision of $2,489,141, partially offset by a deferred tax benefit of $371,900.

Not applicable.

Index to Financial Statements

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Stockholders

The Reserve Petroleum Company

We have audited the accompanying balance sheets of The Reserve Petroleum Company as of December 31, 2015 and 2014, and the related statements of operations, stockholders’ equity, and cash flows for the years then ended. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.

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

In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of The Reserve Petroleum Company as of December 31, 2015 and 2014, and the results of its operations and its cash flows for the years then ended, in conformity with U.S. generally accepted accounting principles.

/s/ HoganTaylor LLP

Oklahoma City, Oklahoma

March 30, 2016

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 OPERATIONS

See Accompanying Notes

THE RESERVE PETROLEUM COMPANY

STATEMENTS OF STOCKHOLDERS’ EQUITY

FOR THE YEARS ENDED DECEMBER 31, 2015 AND 2014

See Accompanying Notes

THE RESERVE PETROLEUM COMPANY

STATEMENTS OF CASH FLOWS

See Accompanying Notes

THE RESERVE PETROLEUM COMPANY

STATEMENTS OF CASH FLOWS

See Accompanying Notes

THE RESERVE PETROLEUM COMPANY

NOTES TO FINANCIAL STATEMENTS

UNAUDITED SUPPLEMENTAL FINANCIAL INFORMATION

SUPPLEMENTAL SCHEDULE 1

None.

Disclosure Controls and Procedures

As defined in Rules 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934 (the "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'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's management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate, to allow timely decisions regarding required disclosure.

Management of the Company, with the participation of the Principal Executive Officer and Principal Financial Officer, evaluated the effectiveness of the Company's disclosure controls and procedures and concluded that the Company's disclosure controls and procedures were effective as of December 31, 2015.

Management's Annual Report on Internal Control over Financial Reporting

Management of the Company is responsible for establishing and maintaining adequate internal control over financial reporting for the Company as defined in Rules 13a-15(f) and 15d-15(f) of the Exchange Act. This system is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with accounting principles generally accepted in the United States of America.

The Company's internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the Company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the Company are being made only in accordance with authorizations of management and the directors of the Company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the Company's assets that could have a material effect on the financial statements, and provide reasonable assurance as to the detection of fraud.

Because of its inherent limitations, a system of internal control over financial reporting can provide only reasonable assurance and may not prevent or detect misstatements. Further, because of changes in conditions, effectiveness of internal controls over financial reporting may vary over time.

With the participation of the Principal Executive Officer and Principal Financial Officer, the Company’s management conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting, based on the framework and criteria established in Internal Control-Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. Based on this evaluation, the Company’s management concluded that the Company's internal control over financial reporting was effective as of December 31, 2015.

This Annual Report on Form 10-K does not include an attestation report of the Company’s independent registered public accounting firm regarding internal control over financial reporting. As the Company is a Smaller Reporting Company, Management’s report was not subject to attestation by the Company’s independent registered public accounting firm.

Changes in Internal Control over Financial Reporting

Management of the Company, with the participation of the Principal Executive Officer and Principal Financial Officer, evaluated the internal control over financial reporting and concluded that no change in the Company’s internal control over financial reporting occurred during the fourth quarter ended December 31, 2015 that has materially affected, or is reasonably likely to materially affect, the Company's internal control over financial reporting.

None.

PART III

Information regarding directors and executive officers, Section 16(a) Beneficial Ownership Reporting Compliance, the Company’s Code of Ethics, Corporate Governance, and any other information called for by this item is incorporated by reference to the Proxy Statement.

Information regarding executive compensation called for by this Item is incorporated by reference to the Proxy Statement.

Information regarding security ownership of certain beneficial owners and management and related stockholder matters called for by this Item is incorporated by reference to the Proxy Statement.

See Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Item 8, Note 12 to Financial Statements. Information regarding the independence of our directors and other information called for by this Item is incorporated by reference to the Proxy Statement.

Information regarding fees billed to the Company by its independent registered public accounting firm is incorporated by reference to the Proxy Statement.

PART IV

ITEM 15.     EXHIBITS AND FINANCIAL STATEMENT SCHEDULES

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

SIGNATURES

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

Date: March 30, 2016

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

38