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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C.  20549   

 

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FORM 10-Q 

 

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QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(D)

OF THE SECURITIES EXCHANGE ACT OF 1934

 

 

(Exact name of registrant as specified in its charter)

 

1870 Cordell Court, Suite 210

(Address of principal executive offices) (Zip Code)

 

(Registrant’s telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the past 12 months (or for such shorter period that the registrant was required to file such reports), and  (2) has been subject to such filing requirements for the past 90 days.                 Yes  ☒    No  ☐

 

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).              Yes ☒     No ☐

 

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company or an emerging growth company (as defined in Rule 12b-2 of the Exchange Act).  Check one:

 

 

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 financial 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 Act).               Yes ☐    No ☒

 

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

 

At August 2, 2017, a total of 21,839,592 shares of registrant’s common stock were outstanding.

 

TABLE OF CONTENTS

 

 

 

PART I.   FINANCIAL INFORMATION

Item 1.  Financial Statements

 

ROYALE ENERGY, INC.

BALANCE SHEETS

 

 

See notes to unaudited financial statements.

ROYALE ENERGY, INC.

BALANCE SHEETS

 

 

See notes to unaudited financial statements.

ROYALE ENERGY, INC.

STATEMENTS OF OPERATIONS

FOR THE PERIODS ENDED JUNE 30, 2017 AND 2016

 

See notes to unaudited financial statements.

 

ROYALE ENERGY, INC.

STATEMENTS OF CASH FLOWS

FOR THE SIX MONTHS ENDED JUNE 30, 2017 AND 2016

See notes to unaudited financial statements.

 

ROYALE ENERGY, INC.

NOTES TO UNAUDITED FINANCIAL STATEMENTS

NOTE 1 – In the opinion of management, the accompanying unaudited financial statements include all adjustments, consisting only of normally recurring adjustments, necessary to present fairly the Company’s financial position and the results of its operations and cash flows for the periods presented.  The results of operations for the three month period are not, in management’s opinion, indicative of the results to be expected for a full year of operations.  It is suggested that these financial statements be read in conjunction with the financial statements and the notes thereto included in the Company’s latest annual report.

Merger with Matrix Oil Management Corporation

In July 2016, the Company entered into a letter of intent with Matrix Oil Management Corporation (“Matrix”) to merge Royale Energy and Matrix in a combined stock and assumption of debt transaction.  On November 30, 2016, the Company entered into an Agreement and Plan of Merger and Reorganization dated November 30, 2016, among Royale, Royale Energy Holdings, Inc., a Delaware corporation (the “Parent”), Royale Merger Sub, Inc., a California corporation and wholly-owned subsidiary of Parent, Matrix Merger Sub, Inc., a California corporation and wholly-owned subsidiary of Parent, and Matrix.  The Merger Agreement was subsequently amended and restated as of December 31, 2016, and amended again as of March 31 and June 30, 2017 (the “Merger Agreement”).

 

The Merger Agreement is part of a series of related transactions in which the Parent will (i) issue its common stock to acquire all of (A) the common stock of Royale Energy, Matrix and Matrix’s affiliate, Matrix Oil Corporation, a California corporation, and (B) the partnership interests of three limited partnerships affiliated with Matrix and (ii) issue newly created Series B 3.5% Convertible Preferred Stock in exchange for approximately $20,398,537 of subordinated debt issued by Matrix and its affiliates.

Immediately after the mergers and the related transactions, it is expected that (i) former holders of Matrix common stock, Matrix Oil Corporation capital stock and the three limited partnerships affiliated with Matrix will collectively own 50% of the Parent’s common stock then outstanding, (ii) former holders of Royale Energy common stock will collectively own 50% of the Parent’s common stock then outstanding, in each case giving effect to the number of shares of the Parent’s common stock issuable under all options and warrants outstanding immediately after the mergers other than shares issuable on exercise of certain options and warrants issued by Royale Energy and (iii) former holders of subordinated debt issued by Matrix and its affiliates will collectively own 100% of all of the Parent’s Series B Convertible Preferred Stock then outstanding.

 

The merger and related transactions will require the approval of the shareholders of each company and registration of the Royale Energy equity securities to be issued in the merger under the Securities Act of 1933 prior to completion of the transaction.  The Merger Agreement will terminate unless extended by agreement of the parties if the merger and related transactions do not close by September 30, 2017, and the failure to close is not due to the failure of the terminating party to perform or comply with any of its covenants or agreements to be performed under the Merger Agreement.

Matrix is an independent oil and natural gas producer based in Santa Barbara, California.  Matrix and its affiliates are privately held by fewer than ten equity holders and partners.

The Pre-Effective Form S-4/A filed by Royale Energy Holdings, Inc., on July 21, 2017, includes a preliminary proxy statement of Royale relating to (i) the Parent Common Stock to be issued in connection with the Mergers, the LP Exchanges, the Matrix Operator Exchange, upon the conversion of any Series B Preferred Stock, or the exercise of any outstanding warrants and options that become exercisable upon the effectiveness of the Mergers, and (ii) the Series B Preferred Stock to be issued in connection with the exchange for Preferred Interests issued by Matrix Investments, L.P. The definitive proxy statement/prospectus, when filed, will include important information about Royale, Matrix, the Matrix LPs and Matrix Operator. Royale also plans to file other relevant documents with the SEC regarding the proposed transaction. INVESTORS AND SECURITY HOLDERS ARE URGED TO CAREFULLY READ THE REGISTRATION STATEMENT, THE PROXY STATEMENT/PROSPECTUS AND OTHER RELEVANT DOCUMENTS FILED WITH THE SEC IF AND WHEN THEY BECOME AVAILABLE BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION ABOUT ROYALE, MATRIX AND THE PROPOSED TRANSACTION. Investors and security holders may obtain these documents when available free of charge at the SEC’s website at www.sec.gov.  In addition, the documents filed with the SEC by Royale can be obtained free of charge from Royale’s website at www.royl.com.

The accompanying financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America and requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.  As reflected in the accompanying financial statements, the Company has negative working capital, losses from operations and negative cash flows from operations.

Material estimates that are particularly susceptible to significant change relate to the estimate of Company oil and gas reserves prepared by an independent engineering consultant.  Such estimates are subject to numerous uncertainties inherent in the estimation of quantities of proven reserves. Estimated reserves are used in the calculation of depletion, depreciation and amortization, unevaluated property costs, impairment of oil and natural gas properties, estimated future net cash flows, taxes, and contingencies.

 

 

The primary sources of liquidity have historically been issuances of common stock and operations. We believe that the completion of the contemplated merger with will enable us to return to positive cash flow.  There is some doubt about the company’s ability to meet liquidity demands, and we anticipate that our primary sources of liquidity will be from the issuance of debt and/or equity, and the sale of oil and natural gas property participation interest.

 

The Company’s consolidated financial statements reflect an accumulated deficit of $46,695,503, a working capital deficiency of $6,659,038 and a stockholders’ deficit of $5,436,304. These factors raise substantial doubt about our ability to continue as a going concern. The accompanying consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

Management’s plans to alleviate the going concern include the proposed merger with Matrix and additional financing through issuances of common stock and the reduction of overhead costs.  There is no assurance that additional financing will be available when needed or that management will be able to obtain financing on terms acceptable to the Company and whether the Company will become profitable and generate positive operating cash flow. If the Company is unable to raise sufficient additional funds, it will have to develop and implement a plan to further extend payables, attempt to extend note repayments, and reduce overhead until sufficient additional capital is raised to support further operations.  There can be no assurance that such a plan will be successful.

 

 

Royale Energy’s primary business is oil and gas production.  Natural gas flows from the wells into gathering line systems, which are equipped occasionally with compressor systems, which in turn flow into metered transportation and customer pipelines.  Monthly price data and daily production are used to invoice customers for amounts due to Royale Energy and other working interest owners.  Royale Energy operates virtually all of its own wells and receives industry standard operator fees.

 

Royale Energy generally sells crude oil and natural gas under short-term agreements at prevailing market prices. Revenues are recognized when the products are delivered, which occurs when the customer has taken title and has assumed the risks and rewards of ownership, prices are fixed or determinable and collectability is reasonably assured.

Revenues from the production of oil and natural gas properties in which the Royale Energy has an interest with other producers are recognized on the basis of Royale Energy’s net working interest. Differences between actual production and net working interest volumes are not significant.

 

Royale Energy’s financial statements include its pro rata ownership of wells.  Royale Energy usually sells a portion of the working interest in each well it drills or participates in to third party investors and retains a portion of the prospect for its own account.  Royale Energy generally retains about a 50% working interest.  All results, successful or not, are included at its pro rata ownership amounts: revenue, expenses, assets, and liabilities as defined in FASB ASC 932-323-25 and 932-360.

 

 

Depreciation, depletion and amortization, based on cost less estimated salvage value of the asset, are primarily determined under either the unit-of-production method or the straight-line method, which is based on estimated asset service life taking obsolescence into consideration.  Maintenance and repairs, including planned major maintenance, are expensed as incurred.  Major renewals and improvements are capitalized and the assets replaced are retired.

 

The project construction phase commences with the development of the detailed engineering design and ends when the constructed assets are ready for their intended use.  Interest costs, to the extent they are incurred to finance expenditures during the construction phase, are included in property, plant and equipment and are depreciated over the service life of the related assets.

 

Royale Energy uses the “successful efforts” method to account for its exploration and production activities.  Under this method, Royale Energy accumulates its proportionate share of costs on a well-by-well basis with certain exploratory expenditures and exploratory dry holes being expensed as incurred, and capitalizes expenditures for productive wells.  Royale Energy amortizes the costs of productive wells under the unit-of-production method.

 

Royale Energy carries, as an asset, exploratory well costs when the well has found a sufficient quantity of reserves to justify its completion as a producing well and where Royale Energy is making sufficient progress assessing the reserves and the economic and operating viability of the project.  Exploratory well costs not meeting these criteria are charged to expense. Other exploratory expenditures, including geophysical costs and annual lease rentals, are expensed as incurred.

 

Acquisition costs of proved properties are amortized using a unit-of-production method, computed on the basis of total proved oil and gas reserves.

 

Capitalized exploratory drilling and development costs associated with productive depletable extractive properties are amortized using unit-of-production rates based on the amount of proved developed reserves of oil and gas that are estimated to be recoverable from existing facilities using current operating methods.  Under the unit-of-production method, oil and gas volumes are considered produced once they have been measured through meters at custody transfer or sales transaction points at the outlet valve on the lease or field storage tank.

 

Production costs are expensed as incurred. Production involves lifting the oil and gas to the surface and gathering, treating, field processing and field storage of the oil and gas. The production function normally terminates at the outlet valve on the lease or field production storage tank. Production costs are those incurred to operate and maintain Royale Energy’s wells and related equipment and facilities. They become part of the cost of oil and gas produced. These costs, sometimes referred to as lifting costs, include such items as labor costs to operate the wells and related equipment; repair and maintenance costs on the wells and equipment; materials, supplies and energy costs required to operate the wells and related equipment; and administrative expenses related to the production activity.

Proved oil and gas properties held and used by Royale Energy are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amounts may not be recoverable.

 

Royale Energy estimates the future undiscounted cash flows of the affected properties to judge the recoverability of carrying amounts. Cash flows used in impairment evaluations are developed using annually updated evaluation assumptions for crude oil commodity prices.  Annual volumes are based on field production profiles, which are also updated annually. Prices for natural gas and other products are based on assumptions developed annually for evaluation purposes.

 

Impairment analyses are generally based on proved reserves.  An asset group would be impaired if the undiscounted cash flows were less than its carrying value.  Impairments are measured by the amount the carrying value exceeds fair value. During the six months ended June 30, 2017 and 2016, impairment losses of $136,837 and $60,237, respectively, were recorded on various capitalized lease and land costs that were no longer viable. 

 

Significant unproved properties are assessed for impairment individually, and valuation allowances against the capitalized costs are recorded based on the estimated economic chance of success and the length of time that Royale Energy expects to hold the properties.  The valuation allowances are reviewed at least annually.

Upon the sale or retirement of a complete field of a proved property, Royale Energy eliminates the cost from its books, and the resultant gain or loss is recorded to Royale Energy’s Statement of Operations.  Upon the sale of an entire interest in an unproved property where the property has been assessed for impairment individually, a gain or loss is recognized in Royale Energy’s Statement of Operations.  If a partial interest in an unproved property is sold, any funds received are accounted for as a recovery of the cost in the interest retained with any excess funds recognized as a gain. Should Royale Energy’s turnkey drilling agreements include unproved property, total drilling costs incurred to satisfy its obligations are recovered by the total funds received under the agreements.  Any excess funds are recorded as a Gain on Turnkey Drilling Programs, and any costs not recovered are capitalized and accounted for under the “successful efforts” method. 

 

Royale Energy sponsors turnkey drilling agreement arrangements in unproved properties as a pooling of assets in a joint undertaking, whereby proceeds from participants are reported as Deferred Drilling Obligations, and then reduced as costs to complete its obligations are incurred with any excess booked against its property account to reduce any basis in its own interest.  Gains on Turnkey Drilling Programs represent funds received from turnkey drilling participants in excess of all costs Royale incurs during the drilling programs (e.g., lease acquisition, exploration and development costs), including costs incurred on behalf of participants and costs incurred for its own account; and are recognized only upon making this determination after Royale’s obligations have been fulfilled.

The contracts require the participants pay Royale Energy the full contract price upon execution of the agreement.   Royale Energy completes the drilling activities typically between 10 and 30 days after drilling begins.  The participant retains an undivided or proportional beneficial interest in the property, and is also responsible for its proportionate share of operating costs.  Royale Energy retains legal title to the lease.  The participants purchase a working interest directly in the well bore.

In these working interest arrangements, the participants are responsible for sharing in the risk of development, but also sharing in a proportional interest in rights to revenues and proportional liability for the cost of operations after drilling is completed and the interest is conveyed to the participant.

 

A certain portion of the turnkey drilling participant’s funds received are non-refundable.  The company holds all funds invested as Deferred Drilling Obligations until drilling is complete.  Occasionally, drilling is delayed for various reasons such as weather, permitting, drilling rig availability and/or contractual obligations.  At June 30, 2017 and December 31, 2016, Royale Energy had Deferred Drilling Obligations of $7,450,467 and $7,894,001, respectively.

 

If Royale Energy is unable to drill the wells, and a suitable replacement well is not found, Royale would retain the non-refundable portion of the contact and return the remaining funds to the participant.  Included in cash and cash equivalents are amounts for use in completion of turnkey drilling programs in progress.

Losses on properties sold are recognized when incurred or when the properties are held for sale and the fair value of the properties is less than the carrying value.

 

Our other receivables consist of receivables from direct working interest investors and industry partners. We provide for uncollectible accounts receivable using the allowance method of accounting for bad debts.  Under this method of accounting, a provision for uncollectible accounts is charged directly to bad debt expense when it becomes probable the receivable will not be collected.  The allowance account is increased or decreased based on past collection history and management’s evaluation of accounts receivable.  All amounts considered uncollectible are charged against the allowance account and recoveries of previously charged off accounts are added to the allowance.  At June 30, 2017 and December 31, 2016, the Company established an allowance for uncollectable accounts of $2,255,542 and $2,270,773, respectively, for receivables from direct working interest investors whose expenses on non-producing wells were unlikely to be collected from revenue.

Our revenue receivables consist of receivables related to the sale of our natural gas and oil.  Once a production month is completed we receive payment approximately 15 to 30 days later.

Equipment and fixtures are stated at cost and depreciated over the estimated useful lives of the assets, which range from three to seven years, using the straight-line method. Repairs and maintenance are charged to expense as incurred. When assets are sold or retired, the cost and related accumulated depreciation are removed from the accounts and any resulting gain or loss is included in income. Maintenance and repairs, which neither materially add to the value of the property nor appreciably prolong its life, are charged to expense as incurred. Gains or losses on dispositions of property and equipment, other than oil and gas, are reflected in operations.

According to Fair Value Measurements and Disclosures Topic of the FASB Accounting Standards Codification, assets and liabilities that are measured at fair value on a recurring and nonrecurring basis in period subsequent to initial recognition, the reporting entity shall disclose information that enable users of its financial statements to assess the inputs used to develop those measurements and for recurring fair value measurements using significant unobservable inputs, the effect of the measurements on earnings for the period.

 

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. In determining fair value, the Company utilizes valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs to the extent possible as well as considers counterparty credit risk in its assessment of fair value. Carrying amounts of the Company’s financial instruments, including cash equivalents, accounts receivable, accounts payable and accrued liabilities, approximate their fair values as of the balance sheet dates because of their generally short maturities.

 

The fair value hierarchy distinguishes between (1) market participant assumptions developed based on market data obtained from independent sources (observable inputs) and (2) an entity’s own assumptions about market participant assumptions developed based on the best information available in the circumstances (unobservable inputs). The fair value hierarchy consists of three broad levels, which gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). The three levels of the fair value hierarchy are described below:

 

Level 1: Quoted prices (unadjusted) in active markets that are accessible at the measurement date for assets or liabilities.

Level 2: Directly or indirectly observable inputs as of the reporting date through correlation with market data, including quoted prices for similar assets and liabilities in active markets and quoted prices in markets that are not active. Level 2 also includes assets and liabilities that are valued using models or other pricing methodologies that do not require significant judgment since the input assumptions used in the models, such as interest rates and volatility factors, are corroborated by readily observable data from actively quoted markets for substantially the full term of the financial instrument.

Level 3: Unobservable inputs that are supported by little or no market activity and reflect the use of significant management judgment. These values are generally determined using pricing models for which the assumptions utilize management’s estimates of market participant assumptions.

 

At June 30, 2017 and December 31, 2016, Royale Energy did not have any financial assets measured and recognized at fair value on a recurring basis.  The Company estimates asset retirement obligations pursuant to the provisions of FASB ASC Topic 410, “Asset Retirement and Environmental Obligations” (“FASB ASC 410”). The initial measurement of asset retirement obligations at fair value is calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with oil and gas properties. Given the unobservable nature of the inputs, including plugging costs and reserve lives, the initial measurement of the asset retirement obligation liability is deemed to use Level 3 inputs.

At June 30, 2017, the components of accounts payable and accrued expenses consisted of $1,492,387 in trade accounts payable due to various vendors, $1,141,156 in payables and accruals related to direct working interest investors and revenues, operating costs and drilling activities, $222,023 in accrued expenses related to current drilling efforts, $266,110 for accrued liabilities for amounts set aside mainly for the plugging and abandonment of certain wells, $118,624 for employee related taxes and accruals, $144,833 related to interest payable on cash advances from pending transactions, $25,701 in deferred rent and $17,123 in federal and state income taxes payable.  At December 31, 2016, the components of accounts payable and accrued expenses consisted of $1,205,740 in trade accounts payable due to various vendors, $699,068 in payables and accruals related to direct working interest investors operating costs, $98,172 in accrued expenses related to current drilling efforts, $266,110 for accrued liabilities for amounts set aside mainly for the plugging and abandonment of certain wells, $103,212 for employee related taxes and accruals, $65,833 related to interest payable on cash advances from pending transactions, $12,446 in deferred rent and $18,662 in federal and state income taxes payable.

 

In July 2016, we received a cash investment of $1,580,000 from two investors to purchase convertible promissory notes of $1,280,000 and $300,000, with a conversion price of $0.40 per share, with warrants to purchase one share of common stock for every three shares of common stock issuable upon conversion of the notes.  The notes matured on August 2, 2017, (one year from the date of issuance) and carry a 10% interest rate, which is due at maturity.  The conversion of the notes to shares is subject to shareholder approval.  The funds from these transactions is to be used to continue drilling activities, fund expenses to be incurred in connection with the completion of Royale Energy’s proposed merger with Matrix Oil Corporation and for general corporate purposes.  The Company has received an extension of the $300,000 obligation until December 31, 2017, and has requested a similar extension of the $1,280,000 obligation.

 

The Company has reviewed the updates issued by the Financial Accounting Standards Board (FASB) during the six months ended June 30, 2017:

ASU 2017-01: Business Combinations (Topic 805) – Clarifying the Definition of a Business

In January 2017, FASB issued ASU 2017-01. The objective of ASU 2017-01 is to clarify the definition of a business by adding guidance on how entities should evaluate whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The definition of a business affects many areas of accounting including acquisitions, disposals, goodwill, and consolidation. ASU 2017-01 will be effective for public business entities for fiscal years beginning after December 15, 2017, including interim periods in the year of adoption. Early adoption is permitted for any interim or annual period. The Company is in the process of determining the impact that the implementation of ASU 2017-01 will have on the Company’s financial statements.

ASU 2016-02: Leases (Topic 842)

In February 2016, FASB issued ASU 2016-02 which aims to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and requiring disclosure of key information about leasing agreements. Entities are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. ASU 2016-02 is effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years. Early adoption is permitted. The Company is currently evaluating the effects of adopting ASU 2016-02 on its consolidated financial statements but the adoption is not expected to have a significant impact on the Company’s consolidated financial statements. 

ASU 2016-09: Compensation—Stock Compensation (Topic 718): Improvements to Employee Share- Based Payment Accounting

In March 2016, FASB issued ASU 2016-09 which amends several aspects of the accounting for share-based payment transactions including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. ASU 2016-09 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted. If early adopted, an entity must adopt all of the amendments in the same period. The Company is currently evaluating the impact of the adoption of ASU 2016-09 on the Company’s financial statements. 

NOTE 2 – LOSS PER SHARE

 

Basic and diluted loss per share are calculated as follows:

 

For the six months ended June 30, 2017 and 2016, Royale Energy had dilutive securities of 0 and 23,331, respectively.  These securities were not included in the dilutive loss per share due to their antidilutive nature.

 

NOTE 3 – OIL AND GAS PROPERTIES, EQUIPMENT AND FIXTURES

Oil and gas properties, equipment and fixtures consist of the following:

 

 

The guidance set forth in the Continued Capitalization of Exploratory Well Costs paragraph of the Extractive Activities Topic of the FASB Accounting Standards Codification requires that we evaluate all existing capitalized exploratory well costs and disclose the extent to which any such capitalized costs have become impaired and are expensed or reclassified during a fiscal period. We did not make any additions to capitalized exploratory well costs pending a determination of proved reserves during the periods in 2017 or 2016. 

NOTE 4 – INCOME TAXES

 

Deferred tax assets and liabilities reflect the net tax effect of temporary differences between the carrying amount of assets and liabilities for financial reporting purposes and amounts used for income tax purposes.  Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion or all of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.  At the end of 2015, management reviewed the reliability of the Company’s net deferred tax assets, and due to the Company’s continued cumulative losses in recent years, the Company concluded it is not “more-likely-than-not” its deferred tax assets will be realized.  As a result, the Company will continue to record a full valuation allowance against the deferred tax assets in 2016.

 

A reconciliation of Royale Energy’s provision for income taxes and the amount computed by applying the statutory income tax rates at June 30, 2017 and 2016, respectively, to pretax income is as follows: 

 

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

Forward Looking Statements

In addition to historical information contained herein, this discussion contains “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995, subject to various risks and uncertainties that could cause our actual results to differ materially from those in the “forward-looking” statements. While we believe our forward looking statements are based upon reasonable assumptions, there are factors that are difficult to predict and that are influenced by economic and other conditions beyond our control. Investors are directed to consider such risks and other uncertainties discussed in documents filed by the Company with the Securities and Exchange Commission.

 

At June 30, 2017, the Company has an accumulated deficit of $46,695,503, a working capital deficiency of $6,659,038 and a stockholders’ deficit of $5,436,304. As a result, our financial statements include a “going concern qualification” reflecting substantial doubt as to our ability to continue as a going concern.  We are seeking to merge with Matrix to increase efficiency and reduce costs to both companies, thereby allowing a return to positive cash flow.  We have no commitments to provide any additional financing and there is no guarantee that we will be able to secure additional financing on acceptable terms, or at all, if needed to fully fund our 2017 drilling budget and to support future operations.

Results of Operations

We recorded net income of $70,662 for the second quarter of 2017, which compares to a net loss of $475,397 in the second quarter of 2016, a $546,059 or 114.9% improvement.  Our total operating expenses increased in the second quarter of 2017 by $92,218 over the second quarter of 2016, mainly due to increased legal and accounting expenses associated with our proposed merger with Matrix.

Our positive results in the second quarter of 2017 resulted mainly from recording $878,533 for drilling and completing one well. We had been unable to drill any wells in the first quarter of 2017 due to wet weather in our Northern California fields. We expect to drill two additional wells in the third quarter of 2017.

For the six months ended June 30, 2017, we had a net loss of $916,982, a $182,735 or 16.6% improvement when compared to net loss of $1,099,717 during the six months ended June 30, 2016.  Total revenues for the first six months of 2017 were $519,906, a decrease of $99,394 or 16.1% from the total revenues of $619,300 during the period in 2016.  The lower revenues were mainly due to reduced supervisory fees during the period in 2017, when compared to 2016, due to a decrease in the number of wells operated by the Company.

During the first six months of 2017, revenues from oil and gas production increased $101,109 or 40.5% to $351,049 from the 2016 six month revenues of $249,940.  This increase was due to higher natural gas commodity prices during the period in 2017.  The net sales volume of natural gas for the six months ended June 30, 2017, was approximately 117,475 Mcf with an average price of $2.95 per Mcf, versus 131,697 Mcf with an average price of $1.89 per Mcf for the period in 2016.  This represents a decrease in net sales volume of 14,222 Mcf or 10.8%.  The decrease in production volume was mainly due to the sale of our Victor Ranch field interests in 2016, which had an effective date of September 1, 2016 and to the natural declines of our existing wells.  For the quarter ended June 30, 2017, revenues from oil and gas production increased $47,883 or 41.3% to $163,706 from the 2016 second quarter revenues of $115,823.  This increase was also due to higher natural gas commodity prices during the quarter in 2017.  The net sales volume of natural gas for the quarter ended June 30, 2017, was approximately 58,287 Mcf with an average price of $2.77 per Mcf, versus 63,361 Mcf with an average price of $1.82 per Mcf for the second quarter of 2016.  This represents a decrease in net sales volume of 5,074 Mcf or 8.0% for the quarter in 2017.

Oil and natural gas lease operating expenses decreased by $108,490 or 32.0%, to $230,453 for the six months ended June 30, 2017, from $338,943 for the same period in 2016.  For the second quarter in 2017, lease operating expenses decreased $29,976 or 19.5% from the same quarter in 2016.  These decreases were mainly due to the sale of our Victor Ranch field interests in 2016 which reduced overhead, pumping and compression costs during the periods in 2017.

The aggregate of supervisory fees and other income was $168,857 for six months ended June 30, 2017, a decrease of $200,503 or 54.3% from $369,360 during the six months in 2016.  During the second quarter 2017, supervisory fees and other income decreased $134,717 or 62.2% when compared to the period in 2016.  These decreases were due to lower supervisory and drilling overhead during the period in 2017 mainly due to the sale of our Victor Ranch field interests in 2016.  

Depreciation, depletion and amortization expense decreased to $90,304 from $149,172, a decrease of $58,868 or 39.5% for the six months ended June 30, 2017, as compared to the same period in 2016.  During the second quarter 2017, depreciation, depletion and amortization expenses decreased $28,525 or 39.6%.   The depletion rate is calculated using production as a percentage of reserves.  These decreases in depreciation expense was due to a lower depletion rate as reserve volumes were higher at the end of 2016 and due to a lower asset base due to the sale of our Victor Ranch field interests in 2016.

General and administrative expenses decreased by $112,642 or 10.0% from $1,127,670 for the six months ended June 30, 2016, to $1,015,028, for the six month period in 2017.  For the second quarter 2017, general and administrative expenses decreased $44,851 or 9.1% when compared to the same period in 2016.  These decreases were primarily due to employee related cost reduction measures and reductions in outside consulting services.  Marketing expense for the six months ended June 30, 2017, increased $58,321, or 56.1%, to $162,232, compared to $103,911 for the same period in 2016.  For the second quarter 2017, marketing expenses increased $48,554 or 81.6% when compared to the second quarter in 2016.   Marketing expense varies from period to period according to the number of marketing events attended by personnel and their associated costs.

Legal and accounting expense increased to $668,283 for the six month period, compared to $232,279 for the same period in 2016, a $436,004 or 187.7% increase.  For the second quarter 2017, legal and accounting expenses increased $116,347 or 160.2%, when compared to the second quarter in 2016.  This increase was primarily due to legal and accounting fees related to the proposed Matrix merger.

At June 30, 2017, Royale Energy had a Deferred Drilling Obligation of $7,450,467.  During the first six months of 2017, we disposed of $1,868,534 of drilling obligations upon completing the drilling of one well, while incurring expenses of $990,001, resulting in a gain of $878,533. During the same six month period in 2016, we disposed of $1,691,085 of drilling obligations upon completing the drilling of one well, while incurring expenses of $1,771,097, resulting in a loss of $80,012.  Royale Energy expects to drill two wells during the third quarter of 2017.

During the six months ended June 30, 2017, we recorded a gain of $73,128 on the settlement of accounts payable.  We periodically review our proved properties for impairment on a field-by-field basis and charge impairments of value to the expense. During the six month periods in 2017 and 2016, we recorded lease impairments of $136,837 and $60,237, respectively, on various lease and land costs that were no longer viable.  During the periods in 2017 and 2016, we recorded write downs of $6,000 and $19,151, respectively, on certain well equipment that was no longer useable.  During the six months ended June 30, 2016, we recorded a gain of $198,975 on the sale of our Company owned office building located in El Cajon, California.  Also during the period in 2016, we recorded a gain of $240,885 on the settlement of accounts payable. 

Interest expense increased to $79,412 for the six months ended June 30, 2017, from $47,502 for the same period in 2016, a $31,910 or 67.2% increase.  This increase resulted from interest accrued on its convertible promissory notes issued in August 2016.  The interest during the period in 2016 was primarily related to the outstanding loan for the corporate headquarters.  Further details concerning Royale’s notes payable can be found in Capital Resources and Liquidity, below.   

Capital Resources and Liquidity

At June 30, 2017, Royale Energy had current assets totaling $5,799,386 and current liabilities totaling $12,458,424 a $6,659,038 working capital deficit.  We had cash at June 30, 2017, of $4,216,824 compared to $4,994,598 at December 31, 2016.

Ordinarily, we fund our operations and cash needs from our available credit and cash flows generated from operations.  We believe that, should the merger be consummated, for the foreseeable future we will be able to meet our liquidity demands.  However, should the merger fail to close, there is doubt as to the ability to meet liquidity demands through cash flow or ongoing operations.  In that event, the Company will seek alternative capital sources through additional sales of equity or debt securities.

 

At June 30, 2017, our other receivables, which consist of receivables from direct working interest investors and industry partners, totaled $792,912, compared to $676,647 at December 31, 2016, a $116,265 or 17.2% increase.  This increase was mainly due to receivables from investors for workovers on a non-operated well.  At June 30, 2017, Royale’s revenue receivable was $147,940, a decrease of $155,588 or 51.3%, compared to $303,528 at December 31, 2016, due to lower oil and gas production volumes when compared to year end 2016 due to the sale Victor Ranch leases in 2016.  At June 30, 2017, our accounts payable and accrued expenses totaled $3,427,957, an increase of $958,712 or 38.8% from the accounts payable at December 31, 2016 of $2,469,245, mainly related to current drilling activity and non-operated workover costs. 

In July 2016, we received a cash investment of $1,580,000 from two investors to purchase convertible promissory notes of $1,280,000 and $300,000, with a conversion price of $0.40 per share, with warrants to purchase one share of common stock for every three shares of common stock issuable upon conversion of the notes.  The notes mature one year from the date of issuance and carry a 10% interest rate, which is due at maturity.  The conversion of the notes to shares is subject to shareholder approval.   The funds from these transactions is to be used to continue drilling activities, fund expenses to be incurred in connection with completion of Royale’s proposed merger with Matrix Oil Corporation and for general corporate purposes.  The maturity date of one of the notes for $300,000 has been extended to December 31, 2017.  The Company has requested an extension of the other note.

In December of 2013, Royale purchased an office building for $2,000,000, of which $500,000 was paid in cash on the date of purchase, and $1,500,000 was borrowed from AmericanWest Bank, with a note secured by the property being purchased.  The note carried an interest rate of 5.75% until paid in full. In February 2016, Royale Energy entered into a purchase and sale agreement for the sale of the office building for $2.5 million.  In June 2016, the sale of the building was completed which resulted in a gain of $198,975 and the related principal and interest payments were paid in full.

 

Operating Activities.  Net cash used by operating activities totaled $1,149,332 and $1,462,947 for the six month periods ended June 30, 2017 and 2016, respectively.  This $313,615 or 21.4% decrease in cash used was mainly due to higher accounts payable and accrued expenses at the end of the period in 2017 which was related to drilling activity during the period.  During the six months ended June 30, 2017 and 2016, executive management and directors received 42,020 and 1,505,982, respectively, in compensatory shares of the Company’s common stock valued at $18,750 and $278,352, respectively.

 

Investing Activities.  Net cash provided by investing activities totaled $371,558 and $1,843,135 for the six month periods ended June 30, 2017 and 2016, respectively.  This $1,471,577 decrease in net cash provided can be mainly attributed to proceeds of approximately $936,000 received from the sale of our office building during the period in 2016.

 

Financing Activities.  Net cash used by financing activities totaled $1,242,969 in the first six months of 2016.  During the period in 2016, $1,446,853 was used for principal payments on the Company’s note payable in the sale of its office building.   Also during the period in 2016, we issued 622,316 restricted common shares and received cash proceeds of $200,000 under a private placement stock sale. 

Item 3.  Quantitative and Qualitative Disclosures About Market Risk

 

Our major market risk exposure relates to pricing of oil and gas production.  The prices we receive for oil and gas are closely related to worldwide market prices for crude oil and local spot prices paid for natural gas production.  Prices have been volatile for the last several years, and we expect that volatility to continue.  Monthly average natural gas prices ranged from a low of $3.12 per Mcf to a high of $3.62 per Mcf for the first six months of 2017.  We have not entered into any hedging or derivative agreements to limit our exposure to changes in oil and gas prices or interest rates.

 

Item 4.  Controls and Procedures

 

As of June 30, 2017, an evaluation was performed under the supervision and with the participation of our management, including our CEO and CFO, of the effectiveness of the design and operation of our disclosure controls and procedures.  These controls and procedures are based on the definition of disclosure controls and procedures in Rule 13a-15(e) and Rule 15d-15(e) promulgated under the Securities Exchange Act of 1934.  A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.  Management identified an internal control deficiency that represents a material weakness in or internal control over financial reporting as of June 30, 2017, in that, certain legal documents, such as debt and equity financing transactions, during the fiscal year were not supported by fully executed agreements.

 

The control deficiency that gave rise to the material weakness did not result in a material misstatement of our financial statements for the six month period ending June 30, 2017.

Because of the material weakness described above, our management was unable to conclude that our internal control over financial reporting was effective as of the end of period to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external reporting purposes in accordance with generally accepted accounting principles. Management is seeking written acknowledgement of the note transactions from the note holders in order to remediate the material weakness described above and will require written acknowledgement from counterparties of all similar future transactions.

Except for the actions described above that were taken to address the material weaknesses, there were no changes in our internal controls during the six months ended June 30, 2017 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II.   OTHER INFORMATION

 

Item 1.  Legal Proceedings

 

None

Item 1A.  Risk Factors

Not applicable to smaller reporting companies.

 

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

During the period covered by this report, we have not issued any unregistered shares.

Item 6.  Exhibits

 

Signatures

 

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