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, 2017

 

☐     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)

 

DELAWARE	73-0237060
(State or Other Jurisdiction of Incorporation or Organization)	(I.R.S. Employer Identification No.)
6801 Broadway ext., Suite 300 Oklahoma City, Oklahoma 73116-9037 (405) 848-7551
(Address and telephone number, including area code, of registrant’s principal executive offices)

 

 

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

 

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

 

COMMON STOCK ($0.50 PAR VALUE)

(Title of Class)

 

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, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act:

 

Large accelerated filer	☐			Accelerated filer	☐
Non-accelerated filer	☐	(Do not check if a smaller reporting company)
				Smaller reporting company	☑
				Emerging growth company	☐

 

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised accounting standards provided pursuant to Section 13(a) of the Exchange Act.     ☐

 

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, 2017 (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 $25,095,004, as computed by reference to the last reported sale which was on June 28, 2017.

 

As of March 23, 2018, there were 157,599 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 22, 2018, which will be filed within 120 days of the end of the registrant’s year ended December 31, 2017, are incorporated by reference into Part III of this Form 10-K to the extent described therein.

 

 

 

TABLE OF CONTENTS

 

		Page
Forward-Looking Statements		3
PART I
Item 1.	Business	3
Item 1A.	Risk Factors	5
Item 1B.	Unresolved Staff Comments	5
Item 2.	Properties	5
Item 3.	Legal Proceedings	6
Item 4.	Mine Safety Disclosures	6
PART II
Item 5.	Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities	6
Item 6.	Selected Financial Data	7
Item 7.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	7
Item 7A.	Quantitative and Qualitative Disclosures about Market Risk	13
Item 8.	Financial Statements and Supplementary Data	13
Item 9.	Changes in and Disagreements with Accountants on Accounting and Financial Disclosure	33
Item 9A.	Controls and Procedures	33
Item 9B.	Other Information	34
PART III
Item 10.	Directors, Executive Officers and Corporate Governance	34
Item 11.	Executive Compensation	34
Item 12.	Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters	34
Item 13.	Certain Relationships and Related Transactions and Director Independence	34
Item 14.	Principal Accountant Fees and Services	34
PART IV
Item 15.	Exhibits and Financial Statement Schedules	35
Item 16.	Form 10-K Summary	35

 

 

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 256,133 gross acres equivalent to 88,248 net acres. These mineral interests are located in nine different states in the north and south central United States. A total of 81,115 (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 2017, $1,737,841 (28%) of oil and gas sales was from royalty interests versus $1,487,173 (27%) in 2016. As a result of our mineral ownership, the Company had royalty interests in 15 gross (0.10 net) wells, which were drilled and completed as producing wells in 2017. This resulted in an average royalty interest of about 0.7% for these 15 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 2017, the Company participated in the drilling of 3 development wells with all 3 wells (0.35 net), including 2 wells in progress at year-end 2016, completed as producers.

 

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 to 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 2017, we participated in the drilling of 14 exploratory wells with 4 wells (0.5 net) completed as producers, 3 wells in progress at the end of 2017 and 7 wells (0.95 net) completed as dry holes.

 

For a summation of exploratory and development wells drilled in 2017 or planned for in 2018, 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, 2016.”

 

Customers

 

In 2017, the Company had two customers whose total purchases were greater than 10% of revenues from oil and gas sales. Redland Resources, LLC purchases were $1,417,568 or 23% of total oil and gas sales and Luff Exploration Company purchases were $762,624 or 12% 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.

 

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 and Other 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, 2017, the Company had nine employees, including officers. See the Proxy Statement for additional information. During 2017, 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.

 

ITEM 1A.

RISK FACTORS

 

Not applicable.

 

ITEM 1B.

UNRESOLVED STAFF COMMENTS

 

Not applicable.

 

ITEM 2.

PropertIES

 

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 81% of all properties are located in Oklahoma and Texas and account for approximately 69% of our annual oil and gas sales. About 15% of the properties are located in Arkansas, Kansas and South Dakota and account for approximately 29% of our annual oil and gas sales. The remaining 4% of these properties are located in Colorado, Montana, and Nebraska and account for about 2% of our annual oil and gas sales. No individual property provides more than 10% 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 28 for working interest reserve quantity information.

 

Since January 1, 2017, 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 2016 Annual Report on Form 10-K and federal income tax return for the year ended December 31, 2016. 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, 2017, 2016 and 2015. Equivalent MCF was calculated using approximate relative energy content.

 

		Royalties								Working Interests
		Sales Price								Sales Price								Average Production
		Oil				Gas				Oil				Gas				Cost per
		Per Bbl				Per MCF				Per Bbl				Per MCF				Equivalent MCF
2017		$	47.95			$	2.91			$	46.00			$	2.91			$	2.25
2016		$	38.53			$	2.21			$	36.49			$	2.16			$	1.85
2015		$	47.57			$	2.46			$	43.09			$	2.53			$	1.93

 

At December 31, 2017, the Company had working interests in 200 gross (24.93 net) wells producing primarily gas and 234 gross (23.28 net) wells producing primarily oil. These interests were in 85,255 gross (9,779 net) producing acres. These wells include 49 gross (1.53 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, 2017.

 

		Acreage
		Gross			Net
Non-producing Mineral Interests		256,137			88,248
Undeveloped Leaseholds		86,717			14,490

 

 

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, 2015 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 2017 include the 2 wells still drilling at the end of 2016. As indicated in the “Exploration Program” on Page 4, 3 exploratory wells were still in process at the time of this Form 10-K.

 

		Number of Net Working Interest Wells Drilled
		Exploratory								Development
		Productive				Dry				Productive				Dry
2017			0.50				0.95				0.35				---
2016			0.16				1.41				0.47				---
2015			0.61				0.78				0.68				---

 

Recent Activities

 

See Item 7, under the subheading “Update of Oil and Gas Exploration and Development Activity from December 31, 2016” for a summary of recent activities related to oil and natural gas operations.

 

ITEM 3.

Legal Proceedings

 

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

 

ITEM 4.

MINE SAFETY DISCLOSURES

 

Not applicable.

 

 

PART II

 

Item 5.

Market for REGISTRANT’S Common Equity, Related Stockholder Matters AND ISSUER PURCHASES OF EQUITY SECURITIES

 

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.

 

		Quarterly Ranges
Quarter Ending		High Bid				Low Bid
03/31/16		$	220			$	151
06/30/16		$	199			$	178
09/30/16		$	190			$	182
12/31/16		$	200			$	183
03/31/17		$	245			$	197
06/30/17		$	246			$	211
09/30/17		$	230			$	205
12/31/17		$	226			$	195

 

There was limited public trading in the Company’s common stock in 2017 and 2016. There were 5 brokered trades appearing in the Company’s transfer ledger for 2017 and 9 in 2016.

 

 

At March 23, 2018, the Company had approximately 1,847 record holders of its common stock. The Company paid dividends on its common stock in the amount of $5.00 per share in the second quarter of 2017 and in the second quarter of 2016. 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 2018, if any, with the Board of Directors for its approval.

 

ISSUER PURCHASES OF EQUITY SECURITIES

 

Period		Total Number of Shares Purchased			Average Price Paid Per Share				Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs1			Approximate Dollar Value of Shares that May Yet Be Purchased Under the Plans or Programs1
October 1 to October 31, 2017		36			$	150			---			---
November 1 to November 30, 2017		7			$	150			---			---
December 1 to December 31, 2017		43			$	150			---			---
Total		86			$	150			---			---

 

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.

 

ITEM 6.

SELECTED FINANCIAL DATA

 

Not applicable.

 

ITEM 7.

MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

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’s future operating results will depend upon management’s ability to employ and retain quality employees, generate revenues, and control expenses. Any decline in operating revenues, without corresponding reduction in operating expenses, could have a material adverse effect on our business, results of operations, and financial condition.

 

●

The Company has no significant long-term sales contracts for either oil or gas. For the most part, the price we receive for our product is based upon the spot market price, which in the past has experienced significant fluctuations. Management anticipates price fluctuations will continue in the future, making any attempt at estimating future prices subject to significant uncertainty.

 

●

Exploration costs have been a significant component of the Company’s capital expenditures in the past and are expected to remain so in the near term. Under the successful efforts method of accounting for oil and gas properties which the Company uses, these costs are capitalized if drilling is successful or charged to operating costs and expenses if unsuccessful. Estimating the amount of future costs which may relate to successful or unsuccessful drilling is extremely imprecise at best.

 

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 2018 and any Current Reports on Form 8-K filed by the Company.

 

Critical Accounting Estimates

 

●

Estimates of future revenues from oil and gas sales are derived from a combination of factors which are subject to significant fluctuation over any given period of time. Reserve estimates, by their nature, are subject to revision in the short-term. The evaluating engineer considers production performance data, reservoir data, and geological data available to the Company, as well as makes estimates of production costs, sale prices, and the time period the property can be produced at a profit. A change in any of the above factors can significantly change the timing and amount of net revenues from a property. The Company’s producing properties are composed of many small working interest and royalty interest properties. As a non-operating owner, we have limited access to the underlying data from which working interest reserve estimates are calculated, and estimates of royalty interest reserves are not made because the information required for the estimation is not available to the Company. While reserve estimates are not accounting estimates, they are the basis for impairment, depreciation, depletion, and amortization described below. Additionally, the estimated economic life for each producing property from the reserve estimates is used in the calculation of asset retirement obligations.

 

 

●

The provisions for depreciation, depletion, and amortization of oil and gas properties all constitute critical accounting estimates. Non-producing leaseholds are amortized over the life of the leases using a straight line method; however, when leases are impaired or condemned, an appropriate adjustment to the provision is made at that time.

 

●

The provision for impairment of long-lived assets is determined by review of the estimated future cash flows from the individual properties. A significant, unforeseen downward adjustment in future prices and/or potential reserves could result in a material change in estimated long-lived assets impairment.

 

●

Depletion and depreciation of oil and gas properties are computed using the units-of-production method. A significant, unanticipated change in volume of production or estimated reserves would result in a material, unexpected change in the estimated depletion and depreciation provisions.

 

●

The Company has significant obligations to remove tangible equipment and facilities associated with oil and gas wells and to restore land at the end of oil and gas production operations. Removal and restoration obligations are most often associated with plugging and abandoning wells. Estimating the future restoration and removal costs is difficult and requires estimates and judgments because most of the removal obligations will take effect in the future. Additionally, these operations are subject to private contracts and government regulations that often have vague descriptions of what is required. Asset removal technologies and costs are constantly changing as are regulatory, political, environmental, and safety considerations. Inherent in the present value calculations are numerous assumptions and judgments including the ultimate removal cost amounts, inflation factors, and discount rate.

 

●

Oil and natural gas sales revenue accrual is another critical accounting estimate. The Company does not operate any of its oil and natural gas properties. Obtaining timely production data on all wells from the operators is not feasible; therefore, the Company utilizes past production receipts and estimated sales price information to estimate its accrual of revenue on all wells each quarter. The oil and natural gas sales revenue accrual can be impacted by many variables, including rapid production decline rates, production curtailments by operators, and rapidly changing market prices for oil and natural gas. These variables could lead to an over or under accrual of oil and natural gas sales at the end of any particular quarter. Based on past history, our estimated accrual has been materially accurate.

 

●

The estimation of the amounts of income tax to be recorded by the Company involves interpretation of complex tax laws and regulations as well as the completion of complex calculations, including the determination of the Company’s percentage depletion deduction, if any. To calculate the exact excess percentage depletion allowance, a well-by-well calculation is, and can only be, performed at the end of each year. During interim periods, a high-level estimate is made taking into account historical data and current pricing. Although our management believes its income tax accruals are adequate, differences may occur in the future depending on the resolution of pending and new tax matters.

 

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.

 

Jerry Crow, a director of the Company, is a director of Mesquite and Mid-American. Kyle McLain and Cameron McLain are brothers and directors of the Company. Kyle McLain and Cameron McLain each own more than 7% of the common stock of the Company and are officers. Kyle McLain and Cameron McLain are officers and directors of Mesquite and Mid-American. Kyle McLain and Cameron McLain each own an approximate 11% interest in LLTD.

 

The above named officers, directors, and employees as a group beneficially own approximately 19% of the common stock of the Company, approximately 13% of the common stock of Mesquite, and approximately 10% of the common stock of Mid-American. Each of these three corporations have only one class of stock outstanding. See Item 8, Note 12 to the accompanying financial statements for additional disclosures regarding these relationships.

 

EQUITY AND OTHER INVESTMENTS

 

The Company has a 33% partnership interest in Broadway Sixty-Eight, Ltd. (the “Partnership”), which it accounts 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 Company’s investment in the Partnership totaled $171,243 and $187,380 at December 31, 2017 and 2016, respectively.

 

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. The Company has guaranteed a loan for which the proceeds were used to purchase a portion of the undeveloped real estate acreage. The Company’s investment in the LLC totaled $544,603 and $635,190 at December 31, 2017 and 2016, respectively.

 

The Company’s Equity Investments also include a 20% ownership in QSN Office Park (“QSN”), an Oklahoma limited liability company acquired in March 2016. QSN is constructing and selling office buildings in a new office park. The Company’s investment in QSN totaled $275,248 and $280,000 at December 31, 2017 and 2016, respectively.

 

Other Investments are mostly investments in limited liability companies (“LLC’s”) with smaller ownership interests that do not allow the Company to significantly influence the operations or management of the LLC’s. These investments are recorded at cost and cash distributions from the investment are recognized as income when received. The names of these investments, including ownership interest, investment amounts, the year acquired and a brief description of each, follows.

 

OKC Industrial Properties (“OKC”), 10%, $56,164, acquired in 1992. OKC originally owned approximately 260 acres of undeveloped land in north Oklahoma City and over time has sold all but approximately 46 acres.

 

Bailey Hilltop Pipeline (“Bailey”), 10%, $80,377, acquired in 2008. Bailey is a gas gathering system pipeline for the Bailey Hilltop Prospect oil and gas properties in Grady County, Oklahoma.

 

Cloudburst Solutions (“Solutions”), 8.125%, $1,250,000 total, with an initial investment of $500,000 in 2014 and an additional investment of $750,000 in 2016. Solutions owns exclusive rights to a water purification process technology that is being developed and currently tested.

 

Ocean’s NG (“Ocean”), 12.44%, $206,444, acquired in 2015. Ocean is developing an underground Compressed Natural Gas (“CNG”) storage and delivery system for retail sales of CNG.

 

 

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 2017, 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 2017, net cash provided by operating activities was $2,771,452. Sales (including lease bonuses), net of production costs, general and administrative costs and income taxes paid were $2,394,688, which accounted for 86% of net cash provided by operations. The remaining components provided 14% of cash flow. In 2017, net cash applied to investing activities was $5,202,162. In 2017, dividend payments and treasury stock purchases totaled $873,334 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 increased $86,229 (18%) to $559,936 in 2017 from $473,707 in 2016. The net increase is due to $48,738 in unrealized gains, which represent the change in the fair value of the securities from their original cost, plus $37,491 of 2017 income.

 

Refundable income taxes decreased $209,968 (39%) to $326,830 in 2017 from $536,798 in 2016.

 

Accounts receivable increased $65,183 (9%) to $829,824 in 2017 from $764,641 in 2016. The increase was due primarily to the use of higher product prices for oil and gas sales accrual estimates for year-end 2017 compared to 2016. Additional information about oil and gas sales for 2017 is included in the “Results of Operations” section that follows.

 

In 2017, the Company added a note receivable in the amount of $175,000 to provide funding to a cost method investee.

 

Accounts payable increased $73,258 (45%) to $235,007 in 2017 from $161,749 in 2016. This increase was primarily due to increased drilling activity.

 

Discussion of Selected Material Line Items in Cash Flows. 

 

The following is a discussion of material changes in cash flow by activity between the years ended December 31, 2017 and 2016. 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 2017 were $2,771,452, which, when compared to the $2,776,128 provided in 2016, represents a net decrease of $4,676. The decrease was mostly due to a decrease in lease bonus cash flows of $688,692 that was offset by an increase in oil and gas sales of $682,866. Additional discussion of the significant items follows.

 

 

The $682,866 (13%) increase in cash received from oil and gas sales to $6,029,703 in 2017 from $5,346,837 in 2016 was the result of an increase in oil and gas sales prices partially offset by a decrease in sales volumes. 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 $688,692 (79%) to $184,282 in 2017 from $872,974 in 2016.

 

The 2017 cash distribution from our equity investment in Broadway Sixty-Eight, Ltd. of $49,500 was primarily for our share of operating profits. The 2016 cash distribution of $165,000 included our share of operating profits plus the profits from the sale of the last small office building 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.

 

Investing Activities

 

Net cash applied to investing activities decreased $2,428,826 (32%) to $5,202,162 in 2017 from $7,630,988 in 2016. This $2,428,826 decrease was due primarily to a $1,873,676 decrease in net cash applied to the purchase of available-for-sale securities, a $1,023,556 decrease in purchases of equity and other investments and a $290,000 increase in cash distributions from other investments offset by a $710,580 increase in purchase of property, plant and equipment. See “Equity and Other Investments” discussion on pages 8 and 9 for additional information regarding the investments purchased in 2017 and 2016.

 

Financing Activities

 

Cash applied to financing activities decreased $137,167 (14%) to $873,334 in 2017 from $1,010,501 in 2016. Cash applied to financing activities consist of cash dividends on common stock and cash used for the purchase of treasury stock. In 2017, cash dividends paid on common stock amounted to $837,505 as compared to $921,667 in 2016. Dividends of $5.00 per share were paid in 2017 and 2016. Cash applied to purchase treasury stock decreased $53,005 to $35,829 in 2017 from $88,834 in 2016.

 

Forward-Looking Summary

 

The Company’s latest estimate of business to be done in 2018 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 2017 the Company had net income of $685,687 as compared to net loss of $(84,225) in 2016. Net income/(loss) per share, basic and diluted, was $4.35 in 2017, an increase of $4.88 per share from $(0.53) in 2016. Material line item changes in the Statements of Operations will be discussed in the following paragraphs.

 

Operating Revenues

 

Operating revenues increased $18,452 to $6,309,590 in 2017 from $6,291,138 in 2016. Oil and gas sales increased $707,144 (13%) to $6,125,308 in 2017 from $5,418,164 in 2016. Lease bonuses and other revenues decreased $688,692 (79%) to $184,282 in 2017 from $872,974 in 2016. The increase in oil and gas sales is discussed in the following paragraphs.

 

The $707,144 increase in oil and gas sales was the result of a $234,193 increase in gas sales, a $426,328 increase in oil sales and a $46,623 increase 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 2016 to 2017. Miscellaneous oil and gas product sales of $206,593 in 2017 and $159,970 in 2016 are not included in the analysis.

 

						Variance
Production		2017				Price				Volume				2016
Gas –
MCF (000 omitted)			806								(165)				971
$ (000 omitted)		$	2,346			$	592			$	(358)			$	2,112
Unit Price		$	2.91			$	.74							$	2.17
Oil –
Bbls (000 omitted)			77								(8)				85
$ (000 omitted)		$	3,572			$	732			$	(306)			$	3,146
Unit Price		$	46.42			$	9.52							$	36.90

 

 

The $234,193 (11%) increase in natural gas sales to $2,346,272 in 2017 from $2,112,079 in 2016 was the result of a decrease in gas sales volumes offset by an increase in the average price received per thousand cubic feet (MCF). The average price per MCF of natural gas sales increased $0.74 per MCF to $2.91 per MCF in 2017 from $2.17 per MCF in 2016, resulting in a positive gas price variance of $591,953. A negative volume variance of $357,759 was the result of a decrease in natural gas volumes sold of 164,866 MCF to 806,575 MCF in 2017 from 971,441 MCF in 2016. The decrease in the volume of gas production was the net result of new 2017 production of about 30,000 MCF, offset by a decline of about 194,000 MCF in production from previous wells. About 29,000 MCF (19%) of this decline is from working interest wells in Robertson County, Texas, and another decline of about 43,000 MCF (28%) occurred in working interest wells in Woods County, Oklahoma. 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 not adequate to replace working interest reserves produced in 2017 or 2016.

 

The gas production for 2017 and 2016 includes production from about 100 royalty interest properties drilled by various operators in Robertson County, Texas. These properties accounted for approximately 187,000 MCF and $544,000 of the 2017 gas sales and approximately 216,000 MCF and $468,000 of the 2016 gas sales. These properties accounted for about 23% of the Company’s gas revenues in 2017 and 2016. The Company has no control over the timing of future drilling on the acreage in which we hold mineral interests.

 

The $426,328 (14%) increase in crude oil sales to $3,572,443 in 2017 from $3,146,115 in 2016 was the net result of an increase in the average price per barrel (Bbl) offset by a decrease in oil sales volumes. The average price received per Bbl of oil increased $9.52 to $46.42 in 2017 from $36.90 in 2016, resulting in a positive oil price variance of $732,088. A decline in oil sales volumes of 8,286 Bbls to 76,965 Bbls in 2017 from 85,251 Bbls in 2016 resulted in a negative volume variance of $305,760. The decrease in the oil volume production was the net result of new 2017 production of about 4,000 Bbls, offset by a 13,000 Bbl decline in production from previous wells. Of the new 2017 production, approximately 1,200 Bbls (30%) 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 2017 or 2016.

 

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 $42,735 (1%) to $6,827,906 in 2017 from $6,870,641 in 2016, primarily due to a decrease in depreciation, depletion and amortization expense. The material components of operating costs and expenses are discussed below.

 

Production Costs. Production costs increased $49,264 (2%) to $2,190,020 in 2017 from $2,140,756 in 2016. The net increase was primarily the result of a $69,642 (32%) increase in gross production tax to $285,688 in 2017 from $216,046 in 2016, offset by a decrease in other production costs of $29,195 (7%) to $396,238 in 2017 from $425,433 in 2016. Of the decrease in other production costs, $46,995 was the result of decreased expenses for existing wells offset by $17,800 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 $2,251,662 in 2017 and $1,110,426 in 2016. See Item 8, Note 8 to the accompanying financial statements for a breakdown of these costs. Exploration costs charged to operations were $883,593 in 2017 and $429,210 in 2016, inclusive of unsuccessful exploratory well costs of $630,219 in 2017 and $253,460 in 2016, and geological and geophysical costs of $243,251 in 2017 and $175,749 in 2016.

 

Update of Oil and Gas Exploration and Development Activity from December 31, 2016. For the year ended December 31, 2017, the Company participated in the drilling of 14 gross exploratory working interest wells and 3 gross development working interest wells, including 2 in progress at the end of 2016, with working interests ranging from a high of 16% to a low of 8%. Of the 14 exploratory wells, 4 were completed as producing wells, 7 as dry holes and 3 were in progress. The 3 development wells were completed as producing wells.

 

The following is a summary as of March 7, 2018, updating both exploration and development activity from December 31, 2016, for the period ended December 31, 2017.

 

The Company participated with 8% and 16% working interests in the completion of two development wells that were drilled in 2016 on a Woods County, Oklahoma prospect. Both wells are commercial oil and gas producers. Capitalized costs for the period were $50,195.

 

The Company participated with an 11.1% 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 $60,927.

 

The Company participated with its 8.4% working interest in the drilling of an exploratory well on a Thomas County, Kansas prospect. The well was completed as a marginal oil producer. An additional exploratory well will be drilled on the prospect starting in March 2018. Capitalized costs for the period were $27,214.

 

 

The Company participated with its 10.5% working interest in the drilling of an exploratory well on a Thomas County, Kansas prospect. The well was completed as a dry hole. An additional exploratory well will be drilled on the prospect starting in March 2018. Dry hole costs for the period were $24,292.

 

The Company participated with its 18% working interest in the drilling of two step-out wells (one a re-entry) on a Kiowa County, Kansas prospect. A completion is in progress on one well and the other is awaiting completion. Prepaid drilling costs for the period were $131,400.

 

The Company is participating with its 14% interest in the development of a Hansford County, Texas prospect for waterflooding. Of five planned injection wells, three have been drilled, completed and are injecting water, one has been drilled and completed with water injection to commence shortly and one missed the reservoir and was plugged. There are two producing wells. A water supply well has been drilled and completed and facilities construction is complete. Capitalized costs for the period were $563,458.

 

The Company participated with its 14% working interest in the drilling of two exploratory wells and a salt water disposal well on a Creek County, Oklahoma prospect. One exploratory well was completed as a marginal oil producer and the other as a commercial oil producer. Capitalized costs for the period were $67,473.

 

The Company participated with its 16% working interest in the drilling of an exploratory well on a Chase County, Nebraska prospect. The well was completed as a dry hole. Dry hole costs for the period were $64,402.

 

The Company owns a 35% interest in 16,472.55 net acres of leasehold on a Crockett and Val Verde Counties, Texas prospect. The Company is participating in the development of the prospect and is currently engaged in efforts to sell a portion of its interest.

 

The Company participated with its 14% working interest in the drilling of an exploratory well on a Lavaca County, Texas prospect. The well was completed as a dry hole. Dry hole costs for the period were $245,212.

 

The Company participated with a 35% interest in the development of a Crockett County, Texas prospect on which 4,882.5 net acres of leasehold have been acquired. A geologic study of the prospect area has been completed and the Company has sold a portion of its leasehold rights, leaving it with a 12.25% interest. An exploratory well has been drilled on the prospect and a completion is in progress. Capitalized costs for the period, excluding leasehold, were $22,221. Total leasehold and geologic costs to date for the prospect are $22,856.

 

The Company participated with its 14% interest in a 3-D seismic survey and in the drilling of an exploratory well on a Hodgeman County, Kansas prospect. The well was completed as a dry hole. Dry hole costs for the period were $46,768.

 

In January 2017, the Company purchased a 14% interest in 2,443.84 net acres of leasehold on a Leflore County, Oklahoma prospect for $119,748. The Company participated in the drilling of an exploratory well on the prospect that was completed as a dry hole. Dry hole costs for the period were $123,515.

 

In March 2017, the Company purchased a 16% interest in 587.6 net acres of leasehold on a Harvey County, Kansas prospect for $7,521. A 3-D seismic survey of the prospect area was conducted and an exploratory well was drilled. It was completed as a dry hole. Seismic costs for the period were $8,625 and dry hole costs were $24,879.

 

In March 2017, the Company agreed to purchase a 13% interest in a 3-D seismic prospect covering approximately 35,000 acres in San Patricio County, Texas. The Company’s share of land and seismic costs is estimated to be $646,000 over a two-year period. A 3-D seismic survey of the prospect area has been conducted and the data set is being processed. Exploratory drilling should start sometime in 2018. Capitalized costs for the period were $299,549 and seismic costs were $215,504.

 

In March 2017, the Company paid $8,800 for a 16% interest in 429.36 net acres of leasehold and a producing well on a Comanche County, Kansas prospect. A re-completion attempt of the producing well has been unsuccessful and it is under evaluation. Additional capitalized costs for the period were $26,012.

 

In May 2017, the Company purchased a 10.5% interest in 460.27 net acres of leasehold on a Lea County, New Mexico prospect for $26,580. An exploratory well has been drilled on the prospect and a completion is in progress. Capitalized costs for the period were $259,022.

 

Starting in June 2017, the Company purchased a 10.5% interest in 3,088.44 net acres of leasehold on a Coke County, Texas prospect for $96,003. An exploratory well was drilled on the prospect. A completion attempt was unsuccessful and the well will be plugged. Dry hole costs for the period were $92,815.

 

In September 2017, the Company agreed to take a 7% interest in a Summit County, Utah prospect and to participate in the drilling of an exploratory well on the prospect. The well is in progress. Capitalized costs for the period were $67,956.

 

In December 2017, the Company purchased an 11.2% interest in eleven wells and associated leasehold on a Tyler County, Texas prospect for $56,560 and paid $19,694 in prepaid workover costs. Workovers are in progress on several of the wells and others are planned in an effort to increase production.

 

 

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 $363,431 in 2017 and $390,584 in 2016. The 2017 provision was due to the annual amortization of undeveloped leaseholds. The 2016 provision was due to the annual amortization of undeveloped leaseholds of $334,831 and specific leasehold impairments of $55,753.

 

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 2017 and 2016. The 2017 impairment loss was $426,823 and the 2016 impairment loss was $727,845. The $301,022 decrease in impairments in 2017 was mainly due to fairly stable 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. The Company did not participate in any horizontal working interest wells in 2016 or 2017. 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 $258,914 (16%) to $1,312,058 in 2017 from $1,570,972 in 2016. This decrease is due to the reasons discussed above. The provision also includes $81,035 for 2017 and $113,578 for 2016 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 2017 and 2016. Other income, net increased $383,805 (128%) to $683,397 in 2017 from $299,592 in 2016. The line items responsible for this net increase are described below.

 

Net realized and unrealized gain (loss) on trading securities increased $21,893 to a net gain of $83,622 in 2017 from a net gain of $61,729 in 2016. 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 2017, the Company had realized gains of $34,884 and unrealized gains of $48,738. In 2016, the Company had realized losses of $20,430 and unrealized gains of $82,159.

 

Income from investments increased $290,000 to $445,000 in 2017 from $155,000 in 2016.

 

Gains on asset sales increased $37,560 to $59,683 in 2017 from $22,123 in 2016.

 

Interest income increased $84,128 to $130,498 in 2017 from $46,370 in 2016. This increase was the result of a rise in the average interest rate and 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 increased from 0.33% in 2016 to 0.43% in 2017. The average balance outstanding increased $1,566,628 to $15,412,046 in 2017 from $13,845,418 in 2016.

 

Provision for Income Taxes. In 2017, the Company had an estimated income tax benefit of $582,582 as the result of a deferred tax benefit of $593,111, offset by a current tax provision of $10,529. The deferred tax benefit of $593,111 includes a $577,797 deferred tax benefit adjustment due to a decrease in the federal income tax rate at the end of 2017. In 2016, the Company had an estimated income tax benefit of $172,886 as the result of a current tax benefit of $57,676, plus a deferred tax benefit of $115,210. See Item 8, Note 6 to the accompanying financial statements for an analysis of the various components of income taxes and a discussion of the federal tax rate change.

 

ITEM 7A.

QUANTITATIVE AND QUALiTATIVE DISCLOSURES ABOUT MARKET RISKS

 

Not applicable.

 

ITEM 8.

FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

 

Index to Financial Statements

 

	Page
Report of Independent Registered Public Accounting Firm, HoganTaylor LLP	14
Balance Sheets – December 31, 2017 and 2016	15
Statements of Operations – Years Ended December 31, 2017 and 2016	17
Statements of Stockholders’ Equity – Years Ended December 31, 2017 and 2016	18
Statements of Cash Flows – Years Ended December 31, 2017 and 2016	19
Notes to Financial Statements	21
Unaudited Supplemental Financial Information	28

 

 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

 

 

 

To the Stockholders and the Board of Directors

of The Reserve Petroleum Company

 

 

Opinion on the Financial Statements

We have audited the accompanying balance sheets of The Reserve Petroleum Company (the Company) as of December 31, 2017 and 2016, the related statements of operations, stockholders' equity and cash flows for the years then ended, and the related notes to the financial statements (collectively, the financial statements). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2017 and 2016, and the results of its operations and its cash flows for the years then ended, in conformity with accounting principles generally accepted in the United States of America.

 

Basis for Opinion

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

 

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits we are required to obtain an understanding of internal control over financial reporting 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.

 

Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

 

 

 

/s/ HoganTaylor LLP

 

We have served as the Company's auditor since 2009.

 

Oklahoma City, Oklahoma

March 29, 2018

 

 

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, 2017 AND 2016

 

 

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

 

 

ITEM 9.

CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE

 

None.

 

ITEM 9A.

CONTROLS AND PROCEDURES

 

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, 2017.

 

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, 2017.

 

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.

 

 

 

/s/ Cameron R. McLain		/s/ Lawrence R. Francis
Cameron R. McLain, President		Lawrence R. Francis, 1st Vice President
Principal Executive Officer		Principal Financial Officer
March 29, 2018		March 29, 2018

 

 

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, 2017 that has materially affected, or is reasonably likely to materially affect, the Company's internal control over financial reporting.

 

ITEM 9B.

OTHER INFORMATION

 

None.

 

 

PART III

 

ITEM 10.

DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

 

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.

 

ITEM 11.

EXECUTIVE COMPENSATION

 

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

 

ITEM 12.

SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS

 

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.

 

ITEM 13.

CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS AND DIRECTOR INDEPENDENCE

 

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.

 

ITEM 14.

PRINCIPAL ACCOUNTANT FEES AND SERVICES

 

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.

 

Exhibit Number		Description
3.1		Restated Certificate of Incorporation dated June 1, 2012 is incorporated by reference to Exhibit 3.1 of The Reserve Petroleum Company’s Annual Report 10-K (Commission File No. 0-8157) filed March 28, 2013.
3.2		Amended By-Laws dated November 16, 2004, are incorporated by reference to Exhibit 3.2 of The Reserve Petroleum Company’s Annual Report on Form 10-KSB (Commission File No. 0-8157) filed March 30, 2006.
14		Code of Ethics for Senior Officers incorporated by reference to Exhibit 14 of The Reserve Petroleum Company’s Annual Report on Form 10-KSB (Commission File No. 0-8157) filed March 30, 2006.
31.1*		Certification of Principal Executive Officer Pursuant to Rules 13a-14(a) and 15d-14(a) under the Securities Exchange Act of 1934, as amended.
31.2*		Certification of Principal Financial Officer Pursuant to Rules 13a-14(a) and 15d-14(a) under the Securities Exchange Act of 1934, as amended.
32*		Certification of Principal Executive Officer and Principal Financial Officer Pursuant to 18 U.S.C. Section 1350.
101.INS*		XBRL Instance Document
101.SCH*		XBRL Taxonomy Extension Schema Document
101.CAL*		XBRL Taxonomy Calculation Linkbase Document
101.DEF*		XBRL Taxonomy Definition Linkbase Document
101.LAB*		XBRL Taxonomy Label Linkbase Document
101.PRE*		XBRL Taxonomy Presentation Linkbase Document
		* Filed electronically herewith.

 

ITEM 16.

FORM 10-K SUMMARY

 

None.

 

 

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.

 

	THE RESERVE PETROLEUM COMPANY (Registrant)
	/s/    Cameron R. McLain
	By:  Cameron R. McLain, President
	(Principal Executive Officer)
	/s/    Lawrence R. Francis
	By:  Lawrence R. Francis, 1st Vice President
	(Principal Financial Officer)
Date: March 29, 2018

 

 

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:

 

 

 

/s/ Kyle L. McLain		/s/ Jerry L. Crow
Kyle L. McLain (Chairman of the Board)		Jerry L. Crow (Director)
March 29, 2018		March 29, 2018
/s/ Robert L. Savage		/s/ William M. Smith
Robert L. Savage (Director)		William M. Smith (Director)
March 29, 2018		March 29, 2018

 

 

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