Attached files

file filename
EX-99.1 - REPORT OF GRAVES & CO. CONSULTING LLC - CAMBER ENERGY, INC.ex99-1.htm
EX-32.2 - CERTIFICATION PRINCIPAL FINANCIAL OFFICER - CAMBER ENERGY, INC.ex32-2.htm
EX-32.1 - CERTIFICATION PRINCIPAL EXECUTIVE OFFICER - CAMBER ENERGY, INC.ex32-1.htm
EX-31.2 - CERTIFICATION PRINCIPAL FINANCIAL OFFICER - CAMBER ENERGY, INC.ex31-2.htm
EX-31.1 - CERTIFICATION PRINCIPAL EXECUTIVE OFFICER - CAMBER ENERGY, INC.ex31-1.htm
EX-23.2 - CONSENT OF GRAVES & CO. CONSULTING LLC - CAMBER ENERGY, INC.ex23-2.htm
EX-23.1 - CONSENT OF GBH - CAMBER ENERGY, INC.ex23-1.htm
EX-21.1 - SUBSIDIARIES - CAMBER ENERGY, INC.ex21-1.htm

 

 

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 March 31, 2018

or

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

Commission File Number: 1-32508

CAMBER ENERGY, INC.

(Exact name of registrant as specified in its charter)

Nevada 20-2660243
(State of other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)

 

4040 Broadway, Suite 425, San Antonio, Texas 78209
(Address of principal executive offices) (Zip code)

  

Registrant’s telephone number, including area code: (210) 998-4035

Securities registered pursuant to Section 12(b) of the Act:  

Title of each class Name of each exchange on which registered
Common Stock, $0.001 par value NYSE American

 

Securities registered pursuant to Section 12(g) of the Act:  None

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 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 the 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, 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 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 Exchange Act). Yes ☐  No ☒

Common Stock aggregate market value held by non-affiliates as of the registrant’s most recently completed second fiscal quarter, September 30, 2017: $5,517,761.

 

There were 15,574,255 shares of the registrant’s common stock outstanding as of June 28, 2018.

 

Documents incorporated by reference: none.

 

 

 
 

 

TABLE OF CONTENTS

    Page
  PART I  
ITEM 1. Business. 6
  General 6
  Recent Events 7
  Industry Segments 12
  Operations and Oil and Natural Gas Properties 12
  Marketing 13
  Competition 13
  Regulation 13
  Insurance Matters 14
  Other Matters 14
  Available Information 16
  Glossary of Oil and Gas Terms 16
ITEM 1A. Risk Factors. 20
ITEM 2. Properties. 44
ITEM 3. Legal Proceedings. 48
ITEM 4. Mine Safety Disclosures. 49
 

 PART II

 
ITEM 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities. 50
ITEM 6. Selected Financial Data. 56
ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations. 56
ITEM 7A. Quantitative and Qualitative Disclosures About Market Risk 64
ITEM 8. Financial Statements and Supplementary Data. 64
ITEM 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure. 66
ITEM 9A. Controls and Procedures. 66
ITEM 9B. Other Information. 67
 

 

PART III

 
ITEM 10. Directors, Executive Officers and Corporation Governance.              68
ITEM 11. Executive Compensation. 75
ITEM 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters. 79
ITEM 13. Certain Relationships and Related Transactions, and Director Independence. 81
ITEM 14. Principal Accounting Fees and Services. 84
 

 

PART IV

 
ITEM 15. Exhibits, Financial Statement Schedules. 86
     
  SIGNATURES  

 

 2 
 

 

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

 

 This Annual Report on Form 10-K contains forward-looking statements within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act. These forward-looking statements are generally located in the material set forth under the headings “Risk Factors”, “Management’s Discussion and Analysis of Financial Condition and Results of Operations”, “Business”, and “Properties” but may be found in other locations as well. These forward-looking statements are subject to risks and uncertainties and other factors that may cause our actual results, performance or achievements to be materially different from the results, performance or achievements expressed or implied by the forward-looking statements. You should not unduly rely on these statements. Factors, risks, and uncertainties that could cause actual results to differ materially from those in the forward-looking statements which include, among others,

 

our ability to integrate and realize the benefits of prior and future acquisitions that we may complete;
the availability of funding and the terms of such funding;
our growth strategies;
anticipated trends in our business;
our ability to repay outstanding loans and satisfy our outstanding liabilities;
defaults which have occurred under our senior loan documents and potential foreclosures thereunder;
changes in our business focus and management;
our liquidity and ability to finance our exploration, acquisition and development strategies;
market conditions in the oil and gas industry;
the timing, cost and procedure for future acquisitions;
the impact of government regulation;
estimates regarding future net revenues from oil and natural gas reserves and the present value thereof;
legal proceedings and/or the outcome of and/or negative perceptions associated therewith;
planned capital expenditures (including the amount and nature thereof);
increases in oil and gas production;
changes in the market price of oil and gas;
changes in the number of drilling rigs available;
the number of wells we anticipate drilling in the future;
estimates, plans and projections relating to acquired properties;
our outstanding convertible securities and dilution or negative perceptions associated therewith;
the number of potential drilling locations; and
our financial position, business strategy and other plans and objectives for future operations.

 

We identify forward-looking statements by use of terms such as “may,” “will,” “expect,” “anticipate,” “estimate,” “hope,” “plan,” “believe,” “predict,” “envision,” “intend,” “continue,” “potential,” “should,” “confident,” “could” and similar words and expressions, although some forward-looking statements may be expressed differently. You should be aware that our actual results could differ materially from those contained in the forward-looking statements. You should consider carefully the statements under the “Risk Factors” section of this report and other sections of this report which describe factors that could cause our actual results to differ from those set forth in the forward-looking statements, and the following factors:

 

the possibility that our future acquisitions may involve unexpected costs;
the volatility in commodity prices for oil and gas;
the accuracy of internally estimated proved reserves;
the presence or recoverability of estimated oil and gas reserves;
the ability to replace oil and gas reserves;
the availability and costs of drilling rigs and other oilfield services;
risks inherent in natural gas and oil drilling and production activities, including risks of fire, explosion, blowouts, pipe failure, casing collapse, unusual or unexpected formation pressures, environmental hazards, and other operating and production risks;
delays in receipt of drilling permits;
risks relating to the availability of capital to fund drilling operations that can be adversely affected by adverse drilling results, production declines and declines in natural gas and oil prices;

 

 3 
 

 

 

risks relating to unexpected adverse developments in the status of properties;
risks relating to the absence or delay in receipt of government approvals or other third party consents;
risks relating to governmental regulations regarding hydraulic fracturing and the disposition/disposal of produced water;
environmental risks;
exploration and development risks;
competition;
the inability to realize expected value from acquisitions;
the availability and cost of alternative fuel sources;
our ability to maintain the listing of our common stock on the NYSE American;
our limited market capitalization;
our ability to meet the covenants in our loan agreements and the consequences of not meeting such covenants;
the ability of our management team to execute its plans to meet its goals; and
other economic, competitive, governmental, legislative, regulatory, geopolitical and technological factors that may negatively impact our businesses, operations and pricing.

 

Forward-looking statements speak only as of the date of this report or the date of any document incorporated by reference in this report. Except to the extent required by applicable law or regulation, we do not undertake any obligation to update forward-looking statements to reflect events or circumstances after the date of this report or to reflect the occurrence of unanticipated events.

 

Where You Can Find Other Information

 

We file annual, quarterly, and current reports, proxy statements and other information with the Securities and Exchange Commission (“SEC”). Our SEC filings are available to the public over the Internet at the SEC’s website at www.sec.gov and are available for download, free of charge, soon after such reports are filed with or furnished to the SEC, on the “Investors,” “SEC Filings” page of our website at www.camber.energy. Information on our website is not part of this report, and we do not desire to incorporate by reference such information herein. You may also read and copy any documents we file with the SEC at the SEC’s Public Reference Room at 100 F Street N.E., Washington, D.C. 20549. You can also obtain copies of the documents upon the payment of a duplicating fee to the SEC. Please call the SEC at 1-800-SEC-0330 for further information on the operation of the Public Reference Room. The SEC maintains an Internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC like us. Our SEC filings are also available to the public from the SEC’s website at http://www.sec.gov. Copies of documents filed by us with the SEC are also available from us without charge, upon oral or written request to our Secretary, who can be contacted at the address and telephone number set forth on the cover page of this report.

 

General Information

 

The following discussion and analysis provides information which management believes is relevant for an assessment and understanding of the results of operations and financial condition of the Company. Expectations of future financial condition and results of operations are based upon current business plans and may change. The discussion should be read in conjunction with the audited financial statements and notes thereto.

 

In this report, we may rely on and refer to information regarding our industry which comes from market research reports, analyst reports and other publicly available information. Although we believe that this information is reliable, we cannot guarantee the accuracy and completeness of this information, and we have not independently verified any of it.

 

Unless the context requires otherwise, references to the “Company,” “we,” “us,” “our,” “Camber” and “Camber Energy, Inc.” refer specifically to Camber Energy, Inc., and our consolidated subsidiaries, CATI Operating, LLC, a Texas limited liability company, which was wholly-owned (“CATI”) until it was divested on November 9, 2017, CEI Operating LLC, a Texas limited liability company, which is wholly-owned, Camber Permian LLC, a Texas limited liability company, which is wholly-owned, Camber Permian II LLC, a Texas limited liability company, which was wholly-owned, and CE Operating, LLC, an Oklahoma limited liability company, which was wholly-owned until it was divested on November 9, 2017.

 4 
 

 

Certain abbreviations and oil and gas industry terms used throughout this Annual Report are described and defined in greater detail under “Glossary of Oil and Natural Gas Terms” on page 16, and readers are encouraged to review that section.

In addition, unless the context otherwise requires and for the purposes of this report only:

 

  “Exchange Act” refers to the Securities Exchange Act of 1934, as amended;
  “SEC” or the “Commission” refers to the United States Securities and Exchange Commission; and
  “Securities Act” refers to the Securities Act of 1933, as amended.

 

 

 5 
 

 

PART I

 

ITEM 1. BUSINESS.

 

General

 

Camber Energy, Inc., a Nevada corporation, is an independent oil and natural gas company based in San Antonio, Texas. We are engaged in the acquisition, development and sale of crude oil, natural gas and natural gas liquids from various known productive geological formations, including from the Hunton formation in Lincoln, Logan, Payne and Okfuskee Counties, in central Oklahoma; the Cline shale and upper Wolfberry shale in Glasscock County, Texas; and Hutchinson County, Texas, in connection with our Panhandle acquisition which closed in March 2018 (described below). Incorporated in Nevada in December 2003 under the name Panorama Investments Corp., the Company changed its name to Lucas Energy, Inc., effective June 9, 2006 and effective January 4, 2017, the Company changed its name to Camber Energy, Inc.

On December 30, 2015, the Company entered into an Asset Purchase Agreement (as amended from time to time, the “Asset Purchase Agreement”) to acquire, from twenty-three different entities and individuals (the “Sellers”), working interests in producing properties and undeveloped acreage (the “Acquisition”), which acquisition transaction was completed on August 25, 2016. The assets acquired include varied interests in two largely contiguous acreage blocks in the liquids-rich Mid-Continent region. In connection with the closing of the acquisition, we assumed approximately $30.6 million of commercial bank debt, issued 520,387 shares of common stock to certain of the Sellers, issued 552,000 shares of Series B Preferred Stock to one of the Sellers and its affiliate, and paid $4,975,000 in cash to certain of the Sellers. The effective date of the Acquisition was April 1, 2016.

 

Our primary value drivers are our reserves, which must be developed to unlock their full potential. We believe the market conditions driving us toward the need for a larger entity of greater size and financial mass are even more essential in the current environment. In order to develop the significant reserves at our disposal, we believe that we must become, or become part of, a larger organization with ample cash flow and greater access to capital. Measures such as return on equity, liquidity and stock multiples have led us to conclude that the market, in general, views small-cap and mid-cap exploration and production companies as having greater potential than microcaps. The larger companies tend to have access to more favorable debt financing, receive greater analyst coverage, trade with greater liquidity and consequently, often have higher share prices. We are actively conducting workovers and subject to raising the balance of the funds due in connection with the October 2017 Purchase Agreement (defined and described below), which is subject to certain closing conditions described herein, the Company intends to acquire producing/non producing properties at value prices and participate in joint ventures with industry partners with the goal of enhancing production and cash flow.

The Company also plans to execute a growth strategy by building on the platform and technical capacity created by our recent asset acquisitions described below, provided that the LOI defined and discussed below does not close.  

 

Our website address is http://www.camber.energy. Our fiscal year ends on the last day of March of each year. The information on, or that may be accessed through, our website is not incorporated by reference into this report and should not be considered a part of this report. We refer to the twelve-month periods ended March 31, 2018 and March 31, 2017 as our 2018 Fiscal Year and 2017 Fiscal Year, respectively.

 

As of March 31, 2018, the Company had leasehold interests (working interests) covering approximately 19,985 net acres underlying a total of 78,715 gross acres in its two core regions, Central Oklahoma and West Texas. In Central Oklahoma the Company had 19,126 / 57,947 (net / gross) acres, most of which was acquired pursuant to the Acquisition (defined under Liquidity and Going Concern Consideration). Approximately 97% of the Central Oklahoma acreage is held by production (“HBP”). In West Texas, the Company had 859 /20,768 (net / gross) acres.

 

As of March 31, 2018, Camber was producing an average of approximately 842 net barrels of oil equivalent per day (“Boepd”) from over 100 active well bores. The ratio between the gross and net production varies due to varied working interests and net revenue interests in each well. Our production sales totaled 307,510 barrels of oil equivalent, net to our interest, for the year ended March 31, 2018. At March 31, 2018, Camber’s total estimated proved producing reserves were 2.92 million barrels of oil equivalent of which 1,565,270 barrels (“Bbls”) were crude oil and NGL (“Bbls”) reserves, and 8.15 billion cubic feet (“Bcf”) were natural gas reserves.

 

 

 6 
 

 

 

We have an experienced management team with proven acquisition, operating and financing capabilities. Through May 25, 2018, Mr. Richard Azar, served as Chief Executive Officer. Mr. Azar has over thirty years of extensive oil and gas and financial management experience and since 1982, Mr. Azar’s companies have explored for, produced and operated over 1,000 wells in Central, South and West Texas and Central Oklahoma, including the development of the Hunton Dewatering Resource play in central Oklahoma. Effective May 25, 2018, Mr. Azar resigned as Chief Executive Order in the normal course of business and not due to a disagreement with the Company or in connection with any matter relating to the Company’s operations, policies or practices. Effective on June 21, 2018, Mr. Azar resigned as a member of the Board of Directors.

Effective May 25, 2018, the Board of Directors appointed Mr. Louis G. Schott as Interim Chief Executive Officer. Mr. Schott has over 24 years of legal and business experience with 20 years in the oil and gas industry, including a strong background in restructuring, mergers and acquisitions, public company regulations and requirements, title, energy finance, business development, general negotiations and land. Mr. Schott’s recent restructuring experience includes restructurings within and outside of bankruptcy and both public, traded on the TSX and NYSE American, and private entities. At the time of his appointment, Mr. Schott was an advisor to the Company (a position he has held since December 2017) and is also an advisor to other companies in various stages of growth. Mr. Schott oversaw the operations of the Company pursuant to the terms of the Service Agreement described above under “Item 11. Executive Compensation” - “Service Agreement” from April to December 2017.

As of March 31, 2018, Camber had no employees. We utilized contractors on an “as-needed” basis to carry out various functions, including but not limited to field operations, land administration, corporate activity and information technology maintenance.

Broadly, Camber is targeting acquisitions in the southwest United States, inclusive of Oklahoma, Texas and New Mexico, which represent a vast array of oil and gas deposits. As we consider producing properties, we plan to prioritize those with cash flow returns near our current assets that can substantially improve our bottom line. In addition, we will evaluate the property to determine whether it conforms to our experience and technical expertise. Specifically, we prefer relatively shallow (less than 10,000 feet) formations that require horizontal drilling techniques and significant surface infrastructure management, and we are currently evaluating several opportunities to expand our asset acreage. The ultimate success of each transaction will be significantly dependent upon arriving at acceptable terms and the availability of capital, which may not be available on favorable terms, if at all. 

While actively pursuing specific exploration and development activities in the Mid-Continent area, we may not be able to close future acquisitions for a variety of reasons. We have recently made significant strides in improving production from our existing fields where our barrel of oil equivalent per day rates have risen from 617 boepd in March 2017, to a March 2018 rate of 842 boepd. Continued improvement in these rates should result in increased revenue and cash flow. 

In the event the LOI, described and defined below under “Recent Events” closes, the Company may undertake a change in business focus and/or may seek to combine with another company.

 

Recent Events

 

Vantage Transaction

 

On August 2, 2017, and effective June 13, 2017, the Company entered into an agreement with Vantage Fund, LLC (“Vantage” and the “Vantage Agreement”), pursuant to which Vantage agreed to provide up to $6 million of funding to the Company, in the sole discretion of Vantage, with $400,000 provided in the initial tranche (the “Initial Tranche”). The consideration for the Initial Tranche of funding was the assignment to Vantage of all of the Company’s rights and ownership in its then wholly-owned subsidiary Camber Permian II, LLC (“Camber Permian”) which included leaseholds and potential participation rights in undeveloped oil and gas property known as Arrowhead. The Vantage Agreement contained customary indemnification requirements. On July 17, 2017, Vantage provided $120,000 to the Company under the Vantage Note and on July 20, 2017, Vantage provided $30,000 to the Company under the Vantage Note. Vantage was granted a second lien on the Jackrabbit property in connection with the financing. On November 9, 2017, in connection with the sale of the Jackrabbit Acreage, the Company paid Vantage the full amount due on the Vantage Note of $150,000.

 

 

 7 
 

 

Rogers Loan Default and Foreclosure

 

On August 13, 2013, the Company entered into a $7.5 million Letter Loan Agreement with Louise H. Rogers (“Rogers” and such loan, as amended from time to time, the “Rogers Loan”). As a result of various extensions and amendments thereto the Rogers Loan was due and payable on July 31, 2017. The loan was not paid when due and the cure period on the Rogers Loan expired on September 11, 2017. On such date, all principal, interest and unpaid costs thereunder were immediately due and payable (which totaled approximately $9.4 million as of the date of acceleration which amount included $2.1 million of default interest). Prior to the default, CATI Operating, LLC (“CATI”), the Company’s wholly-owned subsidiary and obligor under the loan, had not recorded interest due on the note based on its earlier agreements. As a result of the default, demand and acceleration, CATI recorded the default interest demand of $2.1 million in the three-month period ended December 31, 2017. In September 2017, Rogers foreclosed on the assets of CATI which secured the note. On October 3, 2017, the trustee of those assets, for the benefit of the lender, sold these assets in public auction foreclosure sales which took place in Gonzales County and Karnes County, Texas. The proceeds from the foreclosure sales of approximately $3.5 million were applied against the outstanding indebtedness. The Company recorded an approximate loss on sale of property of approximately $4.1 million in conjunction with the settlement of the approximate $9.4 million of debt and accrued interest and the removal of approximately $1.3 million of remaining ARO.

 

On December 15, 2017, CATI entered into a Release of Mortgage, Deed of Trust, Assignment, Security Agreement, Financing Statement and Fixture Filing (the “Release”) with Rogers. Pursuant to the Release, the Company completed a transaction in which CATI provided Rogers, pursuant to an Assignment of Overriding Royalty Interest (the “Royalty Assignment”), with an overriding royalty (equal to 0.01 of 8/8ths of all oil and gas) on CATI’s remaining leasehold and Rogers released CATI from all remaining indebtedness owed. The Release, which was filed in various counties in Texas on January 22, 2018 and January 23, 2018, discharged approximately $5.8 million in principal and interest outstanding and owed to Rogers, according to Rogers. The effective date of the Release was December 15, 2017. Additionally, the remaining leasehold and ownership of CATI was assigned to Arkose Lease Partners, LLC, a third party (“Arkose”), pursuant to an Assignment of Membership Interest (the “Assignment”), dated November 1, 2017, in exchange for Arkose’s assumption of all plugging and abandonment liabilities of CATI of approximately $1.8 million.

 

October 2017 Purchase Agreement

 

On October 5, 2017, the Company and the Investor entered into the October 2017 Purchase Agreement, pursuant to which (1) the Investor purchased 212 shares of Series C Preferred Stock on the closing date of the agreement, October 4, 2017 (the “Initial Closing”), for $2 million, and agreed, subject to certain closing conditions set forth in the agreement, agreed to purchase (2) 106 shares of Series C Preferred Stock for $1,000,000, 10 days after the Initial Closing (which closing occurred on November 21, 2017); (3) 105 shares of Series C Preferred Stock for $1,000,000, 10 days after the second closing (which closing occurred on December 27, 2017); (4) 105 shares of Series C Preferred Stock for $1,000,000, 10 days after the third closing (which closing occurred on January 30, 2018); (5) 105 shares of Series C Preferred Stock for $1,000,000, 10 days after the fourth closing; (6) 525 shares of Series C Preferred Stock for $5,000,000, 30 days after the fifth closing; and (7) 525 shares of Series C Preferred Stock for $5,000,000, 30 days after the sixth Closing.

 

On October 5, 2017, in connection with the entry into the October 2017 Purchase Agreement, the Investor purchased 212 shares of Series C Preferred Stock for $2 million (the “Initial Closing”); on November 21, 2017, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 106 shares of Series C Preferred Stock for $1 million (the “Second Closing”); on December 27, 2017, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Third Closing”); on January 31, 2018, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Fourth Closing”); on February 22, 2018, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Fifth Closing”); on March 9, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Sixth Closing”); on April 10, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Seventh Closing”); and on May 22, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Eighth Closing”).

 

 

 8 
 

 

The Sixth Closing, Seventh Closing and Eighth Closing occurred notwithstanding the terms of the October 2017 Purchase Agreement which required the sixth closing to be for a total of $5 million (the “$5 Million Closing”), as the parties mutually agreed to the sales of only $1 million of Series C Preferred Stock to be sold pursuant to the $5 Million Closing, at the Sixth Closing, Seventh Closing and Eighth Closing.

 

On March 2, 2018, the Company and the Investor entered into an amendment to the October 2017 Purchase Agreement (the “Amendment”), pursuant to which the Investor (a) waived any and all Trigger Events (as defined in the certificate of designation of the Series C Preferred Stock (the “Designation”)) that had occurred prior to March 2, 2018, (b) agreed that all calculations provided for in the Designation would be made as if no such Trigger Event had occurred, and (c) waived any right to receive any additional shares of common stock based upon any such Trigger Event, with respect to all shares of Series C Preferred Stock, other than any which have already been converted.

 

The Investor also agreed, pursuant to the Amendment, that the conversion rate of conversion premiums pursuant to the Designation would remain 95% of the average of the lowest 5 individual daily volume weighted average prices during the applicable Measuring Period (as defined in the Designation), not to exceed 100% of the lowest sales prices on the last day of the Measuring Period, less $0.05 per share of common stock, unless a triggering event has occurred, and that such $0.05 per share discount would not be adjusted in connection with the Company’s previously reported 1-for-25 reverse stock split affected on March 5, 2018.

 

The Company plans to use the proceeds from the sale of the Series C Preferred Stock for working capital, workovers on existing wells, acquisitions, repayment of vendor balances and payments to International Bank of Commerce (“IBC”).

 

Consulting Agreements

 

On October 4, 2017, the Company entered into an agreement with a digital marketing advisor pursuant to which the advisor agreed to create original content with the goal of increasing public awareness about the Company and the Company agreed to pay the advisor (a) $20,000 per month beginning in October 2017 and ending on February 28, 2018, (b) $50,000 per month thereafter through October 4, 2018, the end of the term of the agreement, and (c) 100,000 shares of restricted common stock, with 50,000 shares issued in November 2017 and the remainder due on May 1, 2018, which shares have not been issued to date. 

 

On October 4, 2017, the Company entered into a consulting agreement with a third party consultant which consultant agreed to provide investor relations and public relations services to the Company. As consideration pursuant to the agreement, the Company issued the consultant 40,000 shares of restricted common stock (the “Consulting Shares”), with piggy-back registration rights issued in November 2017.

 

On November 13, 2017, the Company entered into a consulting agreement with another third party consulting company whereby the consulting company agreed to act as the Company’s Interim Vice President of Strategy. As consideration pursuant to the agreement, the Company agreed to pay (a) a non-refundable installment of $150,000 upon the execution of the agreement, and (b) beginning on February 1, 2018, the Company will pay $50,000 per month on the first of each month. Effective May 1, 2018, the agreement was modified to reflect compensation payable on an hourly basis.

 

Vantage Agreement 

 

Arrowhead Sale

 

On June 12, 2017, the Company received the initial tranche of $400,000 in connection with the Vantage Agreement. In exchange for the cash received, the Company assigned its interest held in Camber Permian in the undeveloped Arrowhead oil and gas property, with a book value of $114,500, to Vantage and granted warrants to purchase 64,000 shares of the Company’s common stock (see further discussion of these warrants in Note 10). The Company recorded a gain of $1,195 as a result of this assignment that was recorded in loss on sale of property and equipment as of March 31, 2018.

 

Jackrabbit Sale

 

On November 9, 2017, the Company (through its subsidiary, Camber Permian LLC) and NFP Energy LLC (“NFP”), its joint venture partner, sold oil and gas properties totaling approximately 2,452 acres in Gaines County, Texas, to Fortuna Resources Permian, LLC (“Fortuna”), for $1,000 per acre or an aggregate of $2,206,718 payable to the Company (with $245,213 payable to NFP), pursuant to the terms of a letter agreement (the “Sale Agreement”) and an Assignment, Bill of Sale and Conveyance to Fortuna, both dated November 9, 2017 and effective November 1, 2017. This acreage, part of the Company’s “Jackrabbit” acreage, targeted the San Andres formation in the Permian Basin. Additionally, the Company and NFP jointly terminated their venture. With the proceeds from the sale, the Company paid the 1st lien holders, including Alan Dreeben (a former director of the Company), and 2nd lien holder Vantage, thus reducing its liabilities by $1,518,924 and paid NFP $662,072 to terminate the joint venture agreement. The Company maintains a 90% ownership position in the remaining 1,100 acres in the area. The net proceeds from the sale to the Company totaled $25,914.

 

 

 9 
 

 

IBC Bank Loan Default and Forbearances

 

On August 25, 2016, the Company, as borrower, and Richard N. Azar II, our former Chief Executive Officer and former director, and who also received the largest number of securities and cash in connection with the closing of the Acquisition (“Azar”), Donnie B. Seay, our current director, Richard E. Menchaca, RAD2, DBS Investments, Ltd. (“DBS”, controlled by Mr. Seay) and Saxum Energy, LLC (“Saxum”, which is controlled by Mr. Menchaca), as guarantors (collectively, the “Guarantors”, all of which were directly or indirectly Sellers), and IBC, as Lender (“Lender”), entered into a Loan Agreement.

 

Pursuant to the Loan Agreement, the Lender loaned the Company $40 million, evidenced by a Real Estate Lien Note in the amount of $40 million. The Company is required to make monthly payments under the note equal to the greater of (i) $425,000; and (ii) fifty percent (50%) of our monthly net income. The note accrues annual interest at 2% above the prime rate then in effect, subject to a minimum interest rate of 5.5% per annum. The note is due and payable on August 25, 2019. Payments under the note are subject to change as the interest rate changes in order to sufficiently amortize the note in 120 monthly installments. The Company has the right, from time to time and without penalty to prepay the note in whole or in part, subject to the terms thereof.

 

The proceeds of the loan were used to repay and refinance approximately $30.6 million of indebtedness owed by certain of the Sellers, to the Lender (including an aggregate of $18.3 million owed by RAD2 and another entity controlled by Mr. Azar, $9.8 million owed by DBS, and $2.1 million owed by Mr. Menchaca), as well as to pay the $4.975 million due to the Sellers at closing. Another $3.36 million was used to fund a sinking fund required by the Lender, as discussed below, to pay principal on the note.

 

The amount owed under the note is secured by a Security Interest in substantially all of our assets and properties, pursuant to three Security Agreements. Also, each of the Guarantors guaranteed the repayment of a portion of the Loan Agreement pursuant to a Limited Guaranty Agreement. Additionally, in connection with the parties’ entry into the Loan Agreement and to further secure amounts due thereunder, certain of the Guarantors pledged shares of common stock which they received at the closing to the Lender, with RAD2 pledging 124,824 shares of common stock; DBS pledging 37,437 shares of common stock; and Saxum pledging 26,936 shares of common stock.

 

The Loan Agreement also provides that with respect to the properties located in Glasscock County, Texas, which the Company obtained ownership of at the closing of the Acquisition (collectively, the “West Texas Properties”), the Company has the right to sell the West Texas Properties after (i) the Lender approves the purchase and sale agreement in its sole discretion, (ii) the Lender receives as a prepayment of the loan, 50% of the sales proceeds of the West Texas Properties, but in no event less than $2,000,000, and (iii) the balance of the sales proceeds of the West Texas Properties are deposited in the bank account that we are required to maintain with the Lender, to be used to pay certain principal payments of the note as approved by Lender in its sole discretion.

 

The Company agreed to pay the Lender a loan finance charge of $400,000 in connection with its entry into the Loan Agreement, with half due on the date the Company entered into the Loan Agreement and half due on or before the 180th day following the date of the Loan Agreement. As further consideration for agreeing to the terms of the Loan, the Company agreed to issue the Lender 15,612 shares of common stock. The Company recognized a $2.8 million note discount related to these transactions and other debt issuance costs and will amortize the discount and debt issuance costs over the term of the note.

 

As of March 31, 2017, the Company was not in compliance with certain covenants of the loan agreement, including requiring the Company to maintain a net worth of $30 million, and the balance of the loan due to IBC of $38.3 million (less unamortized debt issuance costs of approximately $2.2 million), was recognized as a short-term liability on the Company’s balance sheet as of March 31, 2017. The Company has also recognized approximately $30,000 in accrued interest as of March 31, 2017.

 

On September 8, 2017, the Company received a Notice of Default and Opportunity to Cure (the “Notice”) from IBC, stating that the Company was in default under its loan due to failing to make a required $425,000 loan payment on August 25, 2017 (the “Payment Default”). The Notice was also sent to the guarantors under the Loan Agreement. The Notice also cited the Company for several covenant defaults including exceeding a cap on monthly general and administrative expenses; falling below $30 million of net worth; failing to comply with certain post-closing covenants regarding the assignment of certain oil and gas interests, the execution of certain supplemental mortgages and the completion of certain curative title requirements; failing to pay costs and expenses required pursuant to the terms of the Loan Agreement; failing to meet the requirements of a cash flow test as described in greater detail in the Loan Agreement; and exceeding the loan to value determination provided for in the Loan Agreement. In order to cure the Payment Default described in the Notice, the Company was required to pay $425,000, as well as any attorney’s fees and/or late fees as determined by IBC, on or before September 18, 2017, which amount was not paid and to cure the covenant defaults, which covenant defaults were not cured.

 

 

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Pursuant to extension agreements entered into with IBC, in or around December 2017 and January 2018, (a) IBC agreed to waive the Company’s obligation to make the August 30, 2017, $425,000 monthly principal payment originally due under the IBC loan; (b) the Company confirmed the amount outstanding under the IBC loan ($37,443,308 as of each extension); (c) IBC agreed that interest only payments would be due on September 30, 2017, October 30, 2017, November 30, 2017 and December 31, 2017, with principal payments of $425,000 per month to begin thereafter, which principal payments were not made; (d) the parties agreed that the amounts owed to IBC were payable on demand, provided that if no demand was made, such amounts would be payable by way of monthly payments of $425,000 of principal, plus accrued interest, with the remaining amount owed to IBC due at maturity (August 25, 2019); (e) that the amount owed to IBC will accrue interest at the rate of 2% per annum above the prime rate, subject to a floor of 5.5% (currently 6.25% per annum); (f) if the Company fails to make any payment due to IBC within 10 days of its due date, IBC is due a late payment of 5% of the amount past due (subject to a minimum of $10 and a maximum of $1,500 per late payment); and (g) the Company and the guarantors of the IBC loan released IBC from any claims against IBC as of the date of each of such extensions.

 

The Company subsequently paid the principal payments required as discussed above in February and March 2018, and has further paid all required interest due under the IBC loan through May 2018.

 

As of March 31, 2018, the Company was not in compliance with certain covenants of the loan agreement with IBC, including requiring the Company to maintain a net worth of $30 million and had previously defaulted in the payment of certain interest and principal payments which were required to be paid pursuant to the terms of the loan. As a result, the balance of the loan due to IBC of $36.9 million (less unamortized debt issuance costs of approximately $1.3 million), was recognized as a short-term liability on the Company’s balance sheet as of March 31, 2018. The Company has also recognized approximately $39,000 in accrued interest as of March 31, 2018.

 

Notwithstanding the above extensions, the Company is still in default under the IBC loan, the entire amount of the IBC loan may be accelerated and IBC may take action to enforce its remedies under the loan agreement. The IBC loan is secured by substantially all of the Company’s assets and if IBC were to foreclose on our assets it would have a material adverse effect on our operations and may force us to seek bankruptcy protection.

 

Increase in Authorized Shares of Common Stock

 

Effective on January 10, 2018, the Company filed, with the Secretary of State of Nevada, a Certificate of Amendment to the Company’s Articles of Incorporation to increase the number of the Company’s authorized shares of common stock, $0.001 per value per share, from 200,000,000 shares to 500,000,000 shares.

 

Okfuskee County, Oklahoma Acquisition

 

In January 2018, we acquired approximately 3,000 leasehold acres in Okfuskee County, Oklahoma, including two producing wells and 7 non-producing well bores, in consideration for $210,000. The acquisition included three salt water disposal wells, to support existing and potential future hydrocarbon production.

 

1-for 25 Reverse Stock Split of Outstanding Common Stock

On March 1, 2018, we filed a Certificate of Amendment to the Company’s Articles of Incorporation with the Secretary of State of Nevada to effect a 1-for-25 reverse stock split of all outstanding common stock shares of the Company (the “Amendment”). The reverse stock split was effective on March 5, 2018. The effect of the reverse stock split was to combine each 25 shares of outstanding common stock into one new share, with no change in authorized shares or par value per share, and to reduce the number of common stock shares outstanding from approximately 103.5 million shares to approximately 4.1 million shares (prior to rounding). Proportional adjustments were made to the conversion and exercise prices of the Company’s outstanding convertible preferred stock, warrants and stock options, and to the number of shares issued and issuable under the Company’s stock incentive plans. The reverse stock split did not affect any shareholder’s ownership percentage of the Company’s common stock, except to the limited extent that the reverse stock split resulted in any shareholder owning a fractional share. Fractional shares of common stock were rounded up to the nearest whole share based on each holder’s aggregate ownership of the Company. The effect of the reverse stock split has been retroactively reflected throughout this report.

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Texas Panhandle Acquisition

 

In March 2018, we completed the acquisition of working interests in certain leases, wells and equipment located in the Texas panhandle and a 75% ownership of two partnerships that owned certain leases, wells and equipment in the same fields, for a total purchase price of $250,000, payable in three tranches, from an entity which is controlled by Ian Acrey who serves as the operating manager of our operations through a different entity. A payment of $85,000 was due at closing; $85,000 was due thirty days after closing and $80,000 was due sixty days after closing. Camber earned 25% of the working interest at the closing and earned an additional 25% of the working interest at each of the two subsequent closings. The seller retained a 25% carried working interest in the assets. The acquisition includes 49 non-producing well bores, 5 saltwater disposal wells and the required infrastructure and equipment necessary to support future hydrocarbon production as well as approximately 500 net leasehold acres in Hutchinson County, Texas. Camber is currently evaluating hydrocarbon production opportunities across all of the acquired acreage including the existing non-producing well bores for workover opportunities. An entity which was significantly owned by the operator of the Company’s other operated properties was the seller of the properties.

 

Disposition and IBC Assumption Letter of Intent

 

On June 25, 2018, the Company entered into a non-binding letter of intent with an entity affiliated with Mr. Azar and Donnie B. Seay, our current director (the “LOI”). The LOI contemplates the Company and the entity entering into, among other agreements, an asset purchase agreement whereby the Company will transfer substantially all of its assets to the entity, reserving its assets in Glasscock County and Hutchinson Counties, Texas and will also retain a 12.5% production payment and a 3% overriding royalty interest in its existing Okfuskee County, Oklahoma asset, in consideration for the entity assuming all of the Company’s senior bank debt owed to IBC. The LOI is subject to various conditions, as are the transactions contemplated therein, including, but not limited to, approval of IBC and approval of the Company’s shareholders for the contemplated transactions.

 

Industry Segments

 

Camber Energy’s operations are all crude oil and natural gas exploration and production related.

 

Operations and Oil and Gas Properties

 

We operate and invest in areas that are known to be productive, with a reasonably established production history, in order to decrease geological and exploratory risk. With the closing of the Acquisition in October 2016, the Company acquired over 13,000 net acres in producing fields located primarily in the Mid-Continent region of Oklahoma including Payne, Lincoln and Logan Counties, along with a small amount of interest in production located in Glasscock County, Texas. The Mid-Continent assets produce from a liquids-rich, gas reservoir known as the Hunton formation. These properties include interests in four different fields, of which one is operated by Camber and the other three are non-operated.

 

In January 2018, the Company acquired approximately 3,000 leasehold acres in Okfuskee County, Oklahoma which includes nine currently producing wells and three salt water disposal wells (as described above).

 

Our Glasscock County, Texas properties produce oil and gas primarily from the Wolfberry, Cline and Fusselman formations and are all non-operated. In addition, the Company owns approximately 1,000 net acres and operations in the Permian Basin, Texas which it plans to sell or farm out.

 

In March 2018, the Company acquired 49 non-producing well bores, five salt water disposal wells and approximately 500 net leasehold acres in Hutchinson County, Texas (as described above).

 

We have steered the Company to a strategic path leveraging on our expanding technical and operational “dewatering” expertise. Since closing the acquisition of the Segundo Hunton dewatering assets in August 2016, the Company has sought an opportunity to expand its dewatering expertise to another productive formation. As a simplified explanation, dewatering occurs in formations with high water saturations, greater than 50%. The oil and gas resides in pore spaces of conventional subsurface rock formations and is held in place by the pressurized water. By producing the water (dewatering), the pressure holding the hydrocarbon in place is lowered, the hydrocarbon expands, and transitions from a residual state to a mobile state, allowing for commercial production. This concept is now being used throughout the Mid-Continent to produce large quantities of oil and gas.

 

 

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The Company also plans to execute a growth strategy by building on the platform and technical capacity created by our recent asset acquisitions described below, provided that the LOI does not close.  

 

Marketing

 

We operate exclusively in the onshore United States oil and natural gas industry. Our crude oil and natural gas production sales are to gatherers and marketers with national reputations. Our sales are made on a month-to-month basis, and title transfer occurs when the oil is loaded onto the purchaser’s truck. Crude oil prices realized from production sales are indexed to published posted refinery prices, and to published crude indexes with adjustments on a contract basis.

 

We generally sell a significant portion of our oil and gas production to a relatively small number of customers. For the year ended March 31, 2018, our consolidated revenues were from the sale of oil, gas and natural gas liquids under marketing contracts primarily with Superior Pipeline Company, and Scissortail Energy, LLC. We are not dependent upon any one purchaser and have alternative purchasers available at competitive market prices if there is disruption in services or other events that cause us to search for other ways to sell our production.

 

During the year ended March 31, 2018, two customers accounted for 72.3% of our total revenues and during the year ended March 31, 2017, no one customer accounted for more than 20% of our total revenues. We do not believe the loss of any customer will have a material effect on the Company because alternative customers are readily available.

 

We actively manage our crude oil inventory in field tanks.

 

Competition

 

We are in direct competition for properties with numerous oil and natural gas companies and partnerships exploring various areas of Texas, Oklahoma and elsewhere. Many competitors are large, well-known oil and natural gas and/or energy companies, although no single entity dominates the industry. Many of our competitors possess greater financial and personnel resources, enabling them to identify and acquire more economically desirable energy producing properties and drilling prospects than us. Additionally, there is competition from other fuel choices to supply the energy needs of consumers and industry.

 

Regulation

 

Our operations are subject to various types of regulation at the federal, state and local levels. These regulations include requiring permits for the drilling of wells; maintaining hazard prevention, health and safety plans; submitting notification and receiving permits related to the presence, use and release of certain materials incidental to oil and natural gas operations; and regulating the location of wells, the method of drilling and casing wells, the use, transportation, storage and disposal of fluids and materials used in connection with drilling and production activities, surface plugging and abandonment of wells and the transporting of production. Our operations are also subject to various conservation matters, including the number of wells which may be drilled in a unit and the unitization or pooling of oil and natural gas properties. In this regard, some states allow the forced pooling or integration of tracts to facilitate exploration, while other states rely on voluntary pooling of lands and leases, which may make it more difficult to develop oil and gas properties. In addition, state conservation laws establish maximum rates of production from oil and natural gas wells, generally limiting the venting or flaring of natural gas, and impose certain requirements regarding the ratable purchase of production. The effect of these regulations is to possibly limit the amounts of oil and natural gas we can produce from our wells and to limit the number of wells or the locations at which we can drill.

 

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In the United States, legislation affecting the oil and natural gas industry has been pervasive and is under constant review for amendment or expansion. Pursuant to such legislation, numerous federal, state and local departments and agencies issue recommended new and extensive rules and regulations binding on the oil and natural gas industry and its individual members, some of which carry substantial penalties for failure to comply. These laws and regulations have a significant impact on oil and natural gas drilling, natural gas processing plants and production activities, increasing the cost of doing business and, consequently, affect profitability. Insomuch as new legislation affecting the oil and natural gas industry is common-place and existing laws and regulations are frequently amended or reinterpreted, we may be unable to predict the future cost or impact of complying with these laws and regulations. We consider the cost of environmental protection a necessary and manageable part of our business. We have historically been able to plan for and comply with new environmental initiatives without materially altering our operating strategies.

 

Insurance Matters

 

We maintain insurance coverage which we believe is reasonable per the standards of the oil and natural gas industry. It is common for companies in this industry to not insure fully against all risks associated with their operations either because such insurance is unavailable or because premium costs are considered prohibitive. A material loss not fully covered by insurance could have an adverse effect on our financial position, results of operations or cash flows. We maintain insurance at industry customary levels to limit our financial exposure in the event of a substantial environmental claim resulting from sudden, unanticipated and accidental discharges of certain prohibited substances into the environment. Such insurance might not cover the complete amount of such a claim and would not cover fines or penalties for a violation of an environmental law.

 

Other Matters

 

Environmental. Our exploration, development, and production of oil and natural gas, including our operation of saltwater injection and disposal wells, are subject to various federal, state and local environmental laws and regulations. Such laws and regulations can increase the costs of planning, designing, installing and operating oil, natural gas, and disposal wells. Our domestic activities are subject to a variety of environmental laws and regulations, including but not limited to, the Oil Pollution Act of 1990 (“OPA”), the Clean Water Act (“CWA”), the Comprehensive Environmental Response, Compensation and Liability Act (“CERCLA”), the Resource Conservation and Recovery Act (“RCRA”), the Clean Air Act (“CAA”), and the Safe Drinking Water Act (“SDWA”), as well as state regulations promulgated under comparable state statutes. We are also subject to regulations governing the handling, transportation, storage, and disposal of naturally occurring radioactive materials that are found in our oil and gas operations. Civil and criminal fines and penalties may be imposed for non-compliance with these environmental laws and regulations. Additionally, these laws and regulations require the acquisition of permits or other governmental authorizations before undertaking certain activities, limit or prohibit other activities because of protected areas or species, and impose substantial liabilities for cleanup of pollution.

 

Under the OPA, a release of oil into water or other areas designated by the statute could result in us being held responsible for the costs of remediating such a release, certain OPA specified damages, and natural resource damages. The extent of that liability could be extensive, as set forth in the statute, depending on the nature of the release. A release of oil in harmful quantities or other materials into water or other specified areas could also result in us being held responsible under the CWA for the costs of remediation, and civil and criminal fines and penalties.

 

CERCLA and comparable state statutes, also known as “Superfund” laws, can impose joint and several and retroactive liability, without regard to fault or the legality of the original conduct, on certain classes of persons for the release of a “hazardous substance” into the environment. In practice, cleanup costs are usually allocated among various responsible parties. Potentially liable parties include site owners or operators, past owners or operators under certain conditions, and entities that arrange for the disposal or treatment of, or transport hazardous substances found at the site. Although CERCLA, as amended, currently exempts petroleum, including but not limited to, crude oil, natural gas and natural gas liquids, from the definition of hazardous substance, our operations may involve the use or handling of other materials that may be classified as hazardous substances under CERCLA. Furthermore, the exemption may not be preserved in future amendments of the act, if any.

 

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RCRA and comparable state and local requirements impose standards for the management, including treatment, storage, and disposal, of both hazardous and non-hazardous solid wastes. We generate hazardous and non-hazardous solid waste in connection with our routine operations. From time to time, proposals have been made that would reclassify certain oil and natural gas wastes, including wastes generated during drilling, production and pipeline operations, as “hazardous wastes” under RCRA, which would make such solid wastes subject to much more stringent handling, transportation, storage, disposal, and clean-up requirements. This development could have a significant impact on our operating costs. While state laws vary on this issue, state initiatives to further regulate oil and natural gas wastes could have a similar impact. Because oil and natural gas exploration and production, and possibly other activities, have been conducted at some of our properties by previous owners and operators, materials from these operations remain on some of the properties and in some instances, require remediation. In addition, in certain instances, we have agreed to indemnify sellers of producing properties from which we have acquired reserves against certain liabilities for environmental claims associated with such properties. While we do not believe that costs to be incurred by us for compliance and remediating previously or currently owned or operated properties will be material, there can be no guarantee that such costs will not result in material expenditures.

 

Additionally, in the course of our routine oil and natural gas operations, surface spills and leaks, including casing leaks, of oil or other materials occur, and we incur costs for waste handling and environmental compliance. Moreover, we are able to control directly the operations of only those wells for which we act as the operator. Management believes that we are in substantial compliance with applicable environmental laws and regulations.

 

In response to liabilities associated with these activities, accruals are established when reasonable estimates are possible. Such accruals would primarily include estimated costs associated with remediation. We have used discounting to present value in determining our accrued liabilities for environmental remediation or well closure, but no material claims for possible recovery from third party insurers or other parties related to environmental costs have been recognized in our financial statements. We adjust the accruals when new remediation responsibilities are discovered and probable costs become estimable, or when current remediation estimates must be adjusted to reflect new information.

 

We do not anticipate being required in the near future to expend amounts that are material in relation to our total capital expenditures program by reason of environmental laws and regulations, but inasmuch as such laws and regulations are frequently changed, we are unable to predict the ultimate cost of compliance. More stringent laws and regulations protecting the environment may be adopted in the future and we may incur material expenses in connection with environmental laws and regulations in the future.

 

Occupational Health and Safety. We are also subject to laws and regulations concerning occupational safety and health. Due to the continued changes in these laws and regulations, and the judicial construction of many of them, we are unable to predict with any reasonable degree of certainty our future costs of complying with these laws and regulations. We consider the cost of safety and health compliance a necessary and manageable part of our business. We have been able to plan for and comply with new initiatives without materially altering our operating strategies.

 

Hydraulic Fracturing. Vast quantities of natural gas, natural gas liquids and oil deposits exist in deep shale and other unconventional formations. It is customary in our industry to recover these resources through the use of hydraulic fracturing, combined with horizontal drilling. Hydraulic fracturing is the process of creating or expanding cracks, or fractures, in deep underground formations using water, sand and other additives pumped under high pressure into the formation. As with the rest of the industry, we use hydraulic fracturing as a means to increase the productivity of almost every well that we drill and complete. These formations are generally geologically separated and isolated from fresh ground water supplies by thousands of feet of impermeable rock layers. We follow applicable legal requirements for groundwater protection in our operations that are subject to supervision by state and federal regulators (including the Bureau of Land Management (“BLM”) on federal acreage). Furthermore, our well construction practices require the installation of multiple layers of protective steel casing surrounded by cement that are specifically designed and installed to protect freshwater aquifers by preventing the migration of fracturing fluids into aquifers.

 

Injection rates and pressures are required to be monitored in real time at the surface during our hydraulic fracturing operations. Pressure is required to be monitored on both the injection string and the immediate annulus to the injection string. Hydraulic fracturing operations are required to be shut down if an abrupt change occurs to the injection pressure or annular pressure. These aspects of hydraulic fracturing operations are designed to prevent a pathway for the fracturing fluid to contact any aquifers during the hydraulic fracturing operations.

 

 

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Hydraulic fracture stimulation requires the use of water. We use fresh water or recycled produced water in our fracturing treatments in accordance with applicable water management plans and laws. Several proposals have previously been presented to the U.S. Congress that, if implemented, would either prohibit or restrict the practice of hydraulic fracturing or subject the process to regulation under the Safe Drinking Water Act. Several states have previously considered, or are currently considering, legislation to regulate hydraulic fracturing practices that could impose more stringent permitting, transparency, and well construction requirements on hydraulic-fracturing operations or otherwise seek to ban fracturing activities altogether. Hydraulic fracturing of wells and subsurface water disposal are also under public and governmental scrutiny due to potential environmental and physical impacts, including possible contamination of groundwater and drinking water and possible links to earthquakes. In addition, some municipalities have significantly limited or prohibited drilling activities and/or hydraulic fracturing, or are considering doing so.

 

Restrictions on hydraulic fracturing could make it prohibitive to conduct our operations, and also reduce the amount of oil, natural gas liquids and natural gas that we are ultimately able to produce in commercial quantities from our properties.

 

The Endangered Species Act. The Endangered Species Act (“ESA”) restricts activities that may affect areas that contain endangered or threatened species or their habitats. While some of our assets and lease acreage may be located in areas that are designated as habitats for endangered or threatened species, we believe that we are in substantial compliance with the ESA. However, the designation of previously unidentified endangered or threatened species in areas where we intend to conduct construction activity could materially limit or delay our plans.

 

Global Warming and Climate Change. Various state governments and regional organizations are considering enacting new legislation and promulgating new regulations governing or restricting the emission of greenhouse gases from stationary sources such as our equipment and operations. Legislative and regulatory proposals for restricting greenhouse gas emissions or otherwise addressing climate change could require us to incur additional operating costs and could adversely affect demand for the natural gas and oil that we sell. The potential increase in our operating costs could include new or increased costs to obtain permits, operate and maintain our equipment and facilities, install new emission controls on our equipment and facilities, acquire allowances to authorize our greenhouse gas emissions, pay taxes related to our greenhouse gas emissions and administer and manage a greenhouse gas emissions program.

 

Taxation. Our operations, as is the case in the petroleum industry generally, are significantly affected by federal tax laws. Federal, as well as state, tax laws have many provisions applicable to corporations which could affect our future tax liabilities.

 

Commitments and Contingencies. We are liable for future restoration and abandonment costs associated with our oil and gas properties. These costs include future site restoration, post closure and other environmental exit costs. The costs of future restoration and well abandonment have not been determined in detail. State regulations require operators to post bonds that assure that well sites will be properly plugged and abandoned. We currently operate only in Texas and Oklahoma, which require a security bond based on the number of wells we operate. Management views this as a necessary requirement for operations and does not believe that these costs will have a material adverse effect on our financial position as a result of this requirement.

 

Available Information

 

Our website address is http://www.camber.energy. The information on, or that may be accessed through, our website is not incorporated by reference into this report and should not be considered a part of this report. You can access our filings of Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, current reports on Form 8-K and any amendments to those reports as soon as reasonably practicable after such reports have been filed with the United States Securities and Exchange Commission (SEC). In addition, you can access our proxy statements, our Code of Business Conduct and Ethics, Nominating and Corporate Governance Committee Charter, Audit Committee Charter, and Compensation Committee Charter on our website http://www.camber.energy, at “Investors” – “SEC Filings” – “All SEC Filings” and “Governance” - “Policies”.

 

Our fiscal year ends on the last day of March of each year. We refer to the years ended March 31, 2018 and 2017 as our 2018 and 2017 fiscal years, respectively.

 

GLOSSARY OF OIL AND NATURAL GAS TERMS

 

The following is a description of the meanings of some of the oil and natural gas terms used in this Annual Report.

 

 

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AFE or Authorization for Expenditures. A document that lays out proposed expenses for a particular project and authorizes an individual or group to spend a certain amount of money for that project.

 

Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume, used in this Annual Report in reference to crude oil or other liquid hydrocarbons.

 

Bcf. An abbreviation for billion cubic feet. Unit used to measure large quantities of gas, approximately equal to 1 trillion Btu.

 

Boe. Barrels of oil equivalent, determined using the ratio of one Bbl of crude oil, condensate or natural gas liquids, to six Mcf of natural gas.

 

Boepd. Barrels of oil equivalent per day.

 

Bopd. Barrels of oil per day.

 

Btu or British thermal unit. The quantity of heat required to raise the temperature of one pound of water by one degree Fahrenheit.

 

Completion. The operations required to establish production of oil or natural gas from a wellbore, usually involving perforations, stimulation and/or installation of permanent equipment in the well or, in the case of a dry hole, the reporting of abandonment to the appropriate agency.

 

Condensate. Liquid hydrocarbons associated with the production of a primarily natural gas reserve.

 

Conventional resources. Natural gas or oil that is produced by a well drilled into a geologic formation in which the reservoir and fluid characteristics permit the natural gas or oil to readily flow to the wellbore.

 

Developed acreage. The number of acres that are allocated or assignable to productive wells.

 

Development well. A well drilled into a proved oil or natural gas reservoir to the depth of a stratigraphic horizon known to be productive.

 

Estimated ultimate recovery or EUR. Estimated ultimate recovery is the sum of reserves remaining as of a given date and cumulative production as of that date.

 

Exploratory well. A well drilled to find and produce oil or natural gas reserves not classified as proved, to find a new reservoir in a field previously found to be productive of oil or natural gas in another reservoir or to extend a known reservoir.

 

Farmin or farmout. An agreement under which the owner of a working interest in an oil or natural gas lease assigns the working interest or a portion of the working interest to another party who desires to drill on the leased acreage. Generally, the assignee is required to drill one or more wells in order to earn its interest in the acreage. The assignor usually retains a royalty or reversionary interest in the lease. The interest received by an assignee is a “farmin” while the interest transferred by the assignor is a “farmout.”

 

FERC. Federal Energy Regulatory Commission.

 

Field. An area consisting of a single reservoir or multiple reservoirs all grouped on or related to the same individual geological structural feature and/or stratigraphic condition.

 

Gross acres or gross wells. The total acres or wells in which a working interest is owned.

 

Henry Hub. A natural gas pipeline located in Erath, Louisiana that serves as the official delivery location for futures contracts on the NYMEX. The settlement prices at the Henry Hub are used as benchmarks for the entire North American natural gas market.

 

 

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Held by production. An oil and natural gas property under lease in which the lease continues to be in force after the primary term of the lease in accordance with its terms as a result of production from the property.

 

Horizontal drilling or well. A drilling operation in which a portion of the well is drilled horizontally within a productive or potentially productive formation. This operation typically yields a horizontal well that has the ability to produce higher volumes than a vertical well drilled in the same formation. A horizontal well is designed to replace multiple vertical wells, resulting in lower capital expenditures for draining like acreage and limiting surface disruption.

 

Liquids. Liquids, or natural gas liquids, are marketable liquid products including ethane, propane, butane and pentane resulting from the further processing of liquefiable hydrocarbons separated from raw natural gas by a natural gas processing facility.

 

LOE or Lease operating expenses. The costs of maintaining and operating property and equipment on a producing oil and gas lease.

 

MBbl. One thousand barrels of crude oil or other liquid hydrocarbons.

 

MMBbl/d. One thousand barrels of crude oil or other liquid hydrocarbons per day.

 

Mcf. One thousand cubic feet of natural gas.

 

Mcfgpd. Thousands of cubic feet of natural gas per day.

 

MMcf. One million cubic feet of natural gas.

 

MMBtu. One million British thermal units.

 

Net acres or net wells. The sum of the fractional working interest owned in gross acres or wells.

 

Net revenue interest. The interest that defines the percentage of revenue that an owner of a well receives from the sale of oil, natural gas and/or natural gas liquids that are produced from the well.

 

NGL. Natural gas liquids.

 

NYMEX. New York Mercantile Exchange.

 

Permeability. A reference to the ability of oil and/or natural gas to flow through a reservoir.

 

Petrophysical analysis. The interpretation of well log measurements, obtained from a string of electronic tools inserted into the borehole, and from core measurements, in which rock samples are retrieved from the subsurface, then combining these measurements with other relevant geological and geophysical information to describe the reservoir rock properties.

 

Play. A set of known or postulated oil and/or natural gas accumulations sharing similar geologic, geographic and temporal properties, such as source rock, migration pathways, timing, trapping mechanism and hydrocarbon type.

 

Possible reserves. Additional reserves that are less certain to be recognized than probable reserves.

 

Probable reserves. Additional reserves that are less certain to be recognized than proved reserves but which, in sum with proved reserves, are as likely as not to be recovered.

 

Producing well, production well or productive well. A well that is found to be capable of producing hydrocarbons in sufficient quantities such that proceeds from the sale of the well’s production exceed production-related expenses and taxes.

  

Properties. Natural gas and oil wells, production and related equipment and facilities and natural gas, oil or other mineral fee, leasehold and related interests.

 

 

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Prospect. A specific geographic area which, based on supporting geological, geophysical or other data and also preliminary economic analysis using reasonably anticipated prices and costs, is considered to have potential for the discovery of commercial hydrocarbons.

 

Proved developed reserves. Proved reserves that can be expected to be recovered through existing wells and facilities and by existing operating methods.

 

Proved reserves. Reserves of oil and natural gas that have been proved to a high degree of certainty by analysis of the producing history of a reservoir and/or by volumetric analysis of adequate geological and engineering data.

 

Proved undeveloped reserves or PUDs. Proved reserves that are expected to be recovered from new wells on undrilled acreage or from existing wells where a relatively major expenditure is required for recompletion.

 

Repeatability. The potential ability to drill multiple wells within a prospect or trend.

 

Reservoir. A porous and permeable underground formation containing a natural accumulation of producible oil and/or natural gas that is confined by impermeable rock or water barriers and is individual and separate from other reservoirs.

 

Royalty interest. An interest in an oil and natural gas lease that gives the owner of the interest the right to receive a portion of the production from the leased acreage (or of the proceeds of the sale thereof), but generally does not require the owner to pay any portion of the costs of drilling or operating the wells on the leased acreage. Royalties may be either landowner’s royalties, which are reserved by the owner of the leased acreage at the time the lease is granted, or overriding royalties, which are usually reserved by an owner of the leasehold in connection with a transfer to a subsequent owner.

 

2-D seismic. The method by which a cross-section of the earth’s subsurface is created through the interpretation of reflecting seismic data collected along a single source profile.

 

3-D seismic. The method by which a three-dimensional image of the earth’s subsurface is created through the interpretation of reflection seismic data collected over a surface grid. 3-D seismic surveys allow for a more detailed understanding of the subsurface than do 2-D seismic surveys and contribute significantly to field appraisal, exploitation and production.

 

Trend. A region of oil and/or natural gas production, the geographic limits of which have not been fully defined, having geological characteristics that have been ascertained through supporting geological, geophysical or other data to contain the potential for oil and/or natural gas reserves in a particular formation or series of formations.

 

Unconventional resource play. A set of known or postulated oil and or natural gas resources or reserves warranting further exploration which are extracted from (a) low-permeability sandstone and shale formations and (b) coalbed methane. These plays require the application of advanced technology to extract the oil and natural gas resources.

 

Undeveloped acreage. Lease acreage on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of oil and natural gas, regardless of whether such acreage contains proved reserves. Undeveloped acreage is usually considered to be all acreage that is not allocated or assignable to productive wells.

 

Unproved and unevaluated properties. Refers to properties where no drilling or other actions have been undertaken that permit such property to be classified as proved.

 

Vertical well. A hole drilled vertically into the earth from which oil, natural gas or water flows are pumped.

 

Volumetric reserve analysis. A technique used to estimate the amount of recoverable oil and natural gas. It involves calculating the volume of reservoir rock and adjusting that volume for the rock porosity, hydrocarbon saturation, formation volume factor and recovery factor.

 

Wellbore. The hole made by a well.

 

 

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WTI or West Texas Intermediate. A grade of crude oil used as a benchmark in oil pricing. This grade is described as light because of its relatively low density, and sweet because of its low sulfur content.

 

Working interest. The operating interest that gives the owner the right to drill, produce and conduct operating activities on the property and receive a share of production.

 

ITEM 1A. RISK FACTORS.

 

Our business and operations are subject to many risks. The risks described below may not be the only risks we face, as our business and operations may also be subject to risks that we do not yet know of, or that we currently believe are immaterial. If any of the events or circumstances described below actually occurs, our business, financial condition, results of operations or cash flow could be materially and adversely affected and the trading price of our common stock could decline. The following risk factors should be read in conjunction with the other information contained herein, including the financial statements and the related notes. Please read “Cautionary Note Regarding Forward-Looking Statements” in this filing, where we describe additional uncertainties associated with our business and the forward-looking statements included or incorporated by reference in this filing.

 

Our securities should only be purchased by persons who can afford to lose their entire investment in us. You should carefully consider the following risk factors and other information in this filing before deciding to become a holder of our securities. If any of the following risks actually occur, our business and financial results could be negatively affected to a significant extent.

 

Risks Relating to Our Operations and Industry

We will require substantial additional funding, and our failure to raise additional capital necessary to support and expand our operations could reduce our ability to compete and could harm our business.

 

As of March 31, 2018, we had $0.76 million in cash. Our primary sources of cash for the year ended March 31, 2018 were from funds generated from the sale of preferred stock, the sale of oil and gas properties and the sale of natural gas (including NGL) and crude oil production, and funds borrowed under funding agreements.

 

We do not currently have all of the financial resources to fully develop and execute on all of our other business opportunities, nor do we have all of the resources to satisfy our debt obligations including the loan agreement with International Bank of Commerce (“IBC” or “IBC Bank”), which is currently in default. We intend to finance our development through our producing assets, equity or debt financings and by securing financial and strategic partners focused on development of these opportunities. We can make no assurances that our business operations will provide us with sufficient cash flows to continue our operations. We will need to raise additional capital through equity and debt financing for any new ventures that are developed, for debt services, to support our existing projects and possible expansions thereof and for our corporate general and administrative expenses. We may consider a full range of financing options in order to develop our business.

 

We cannot provide any assurance that any financing will be available to us in the future on acceptable terms or at all. Any such financing could be dilutive to our existing stockholders. If we cannot raise required funds on acceptable terms, we may not be able to, among other things, (i) maintain our general and administrative expenses at current levels; (ii) successfully develop our assets; (iii) fund certain obligations as they become due; (iv) respond to competitive pressures or unanticipated capital requirements; or (v) repay our indebtedness. If we fail to repay or refinance the loan agreement with IBC Bank, which is currently in default, then we may be forced to sell our assets which are secured by the loan agreement with IBC Bank in order to satisfy the outstanding debt or take other remedial steps. If IBC Bank were to foreclose on the assets which secure the IBC Bank debt we may be forced to seek bankruptcy protection, the result of which will likely be, among other things, that any securities in the Company become worthless.

 

 

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We require significant additional financing to continue as a going concern and pay outstanding liabilities and our lack of available funding raises questions regarding our ability to continue as a going concern.

Due to the nature of oil and gas interests, i.e., that rates of production generally decline over time as oil and gas reserves are depleted, if we are unable to drill additional wells and develop our proved undeveloped reserves (“PUDs”), either because we are unable to raise sufficient funding for such development activities, or otherwise, or in the event we are unable to acquire additional operating properties; we believe that our revenues will continue to decline over time. Furthermore, in the event we are unable to raise additional funding in the future we will not be able to participate in the drilling of planned additional wells, will not be able to complete other drilling and/or workover activities, and may not be able to make required payments on our outstanding liabilities, including amounts owed on the loan agreement with IBC Bank. Therefore, in the event we do not raise additional funding in the future we will be forced to scale back our business plan, sell or liquidate assets to satisfy outstanding debts and/or take other steps which may include seeking bankruptcy protection.

These conditions raise substantial doubt about our ability to continue as a going concern for the next twelve months following the issuance of these financial statements. The accompanying financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business. Accordingly, the financial statements do not include any adjustments relating to the recoverability of assets and classification of liabilities that might be necessary should the Company be unable to continue as a going concern. The financial statements included herein also include a going concern footnote from our auditors.

Additionally, due to our need for immediate funding, we may be forced to raise capital through the sale of debt (subordinated to IBC) or equity in the near term. In order to issue additional convertible debt securities, we must, subject to certain exceptions, obtain the consent of the investor in our April 2016/October 2017 financing. If we are unable to obtain the consent of this investor in connection with future financings, we may be unable to raise additional capital on acceptable terms, or at all. If external financing sources are not available in a timely manner or at all, or are inadequate to fund our operations, it could materially harm our financial condition and results of operation. We may not have the time or resources available to seek stockholder approval (if required pursuant to applicable NYSE American rules and requirements) for such transactions which may result in the issuance of more than 20% of our outstanding common stock. As such, we may instead rely on an exemption from the NYSE American stockholder approval rules which allows an NYSE American listed company an exemption from such rules when a delay in securing stockholder approval would seriously jeopardize the financial viability of the Company. Consequently, our stockholders may not be offered the ability to approve transactions we may undertake in the future, including those transactions which would ordinarily require stockholder approval under applicable NYSE American rules and regulations, and/or those transactions which would result in substantial dilution to existing stockholders.

In the event we are unable to raise funding in the future or complete a business combination or similar transaction in the near term, we will not be able to pay our liabilities. In the event we are unable to raise adequate funding in the future for our operations and to pay our outstanding debt obligations or in the event we fail to enter into a business combination or similar transaction, we would be forced to liquidate our assets (or our creditors may undertake a foreclosure of such assets in order to satisfy amounts we owe to such creditors) or may be forced to seek bankruptcy protection, which could result in the value of our outstanding securities declining in value or becoming worthless.

We are currently in default of our $36.9 million loan agreement with IBC Bank, which is secured by substantially all of our assets.

 

On September 8, 2017, the Company received a Notice of Default and Opportunity to Cure (the “Notice”) from IBC, stating that the Company was in default under its loan due to failing to make a required $425,000 loan payment on August 25, 2017 (the “Payment Default”). The Notice was also sent to the guarantors under the Loan Agreement. The Notice also cited the Company for several covenant defaults including exceeding a cap on monthly general and administrative expenses; falling below $30 million of net worth; failing to comply with certain post-closing covenants regarding the assignment of certain oil and gas interests, the execution of certain supplemental mortgages and the completion of certain curative title requirements; failing to pay costs and expenses required pursuant to the terms of the Loan Agreement; failing to meet the requirements of a cash flow test as described in greater detail in the Loan Agreement; and exceeding the loan to value determination provided for in the Loan Agreement. In order to cure the Payment Default described in the Notice, the Company was required to pay $425,000, as well as any attorney’s fees and/or late fees as determined by IBC, on or before September 18, 2017, which amount was not paid and to cure the covenant defaults, which covenant defaults were not cured.

 

 

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Pursuant to extension agreements entered into with IBC, in or around December 2017 and January 2018, (a) IBC agreed to waive the Company’s obligation to make the August 30, 2017, $425,000 monthly principal payment originally due under the IBC loan; (b) the Company confirmed the amount outstanding under the IBC loan ($37,443,308 as of each extension); (c) IBC agreed that interest only payments would be due on September 30, 2017, October 30, 2017, November 30, 2017 and December 31, 2017, with principal payments of $425,000 per month to begin thereafter, which principal payments were not made; (d) the parties agreed that the amounts owed to IBC were payable on demand, provided that if no demand was made, such amounts would be payable by way of monthly payments of $425,000 of principal, plus accrued interest, with the remaining amount owed to IBC due at maturity (August 25, 2019); (e) that the amount owed to IBC will accrue interest at the rate of 2% per annum above the prime rate, subject to a floor of 5.5% (currently 6.25% per annum); (f) if the Company fails to make any payment due to IBC within 10 days of its due date, IBC is due a late payment of 5% of the amount past due (subject to a minimum of $10 and a maximum of $1,500 per late payment); and (g) the Company and the guarantors of the IBC loan released IBC from any claims against IBC as of the date of each of such extensions.

 

As of March 31, 2018, the Company was not in compliance with certain covenants of the loan agreement with IBC, including requiring the Company to maintain a net worth of $30 million and had previously defaulted in the payment of certain interest and principal payments which were required to be paid pursuant to the terms of the loan. As a result, the balance of the loan due to IBC of $36.9 million (less unamortized debt issuance costs of approximately $1.3 million), was recognized as a short-term liability on the Company’s balance sheet as of March 31, 2018. The Company has also recognized approximately $39,000 in accrued interest as of March 31, 2018.

 

Notwithstanding the above extensions, the Company is still in default under the IBC loan, the entire amount of the IBC loan may be accelerated and IBC may take action to enforce its remedies under the loan agreement. The IBC loan is secured by substantially all of the Company’s assets.

 

We have substantial indebtedness which could adversely affect our financial flexibility and our competitive position.  

 

We have a significant amount of outstanding indebtedness. As of March 31, 2018, we owed approximately $3 million in accounts payable and $37.4 million in notes payable, of which $36.9 million is the Loan Agreement with IBC (currently in default).  

 

Our substantial indebtedness could have important consequences and significant effects on our business. For example, it could:

 

  increase our vulnerability to adverse changes in general economic, industry and competitive conditions;
  require us to dedicate a substantial portion of our cash flow from operations to make payments on our indebtedness, thereby reducing the availability of our cash flow to fund working capital, capital expenditures and other general corporate purposes;   restrict us from taking advantage of business opportunities;
  make it more difficult to satisfy our financial obligations;
  place us at a competitive disadvantage compared to our competitors that have less debt obligations; and
  limit our ability to borrow additional funds for working capital, capital expenditures, acquisitions, debt service requirements, execution of our business strategy or other general corporate purposes in satisfactory terms or at all.

 

We will need to raise additional funding in the future to repay or refinance the IBC Loan Agreement (currently in default as discussed above) and our accounts payable, and as such may need to seek additional debt or equity financing. Such additional financing may not be available on favorable terms, if at all. If debt financing is available and obtained, our interest expense may increase and we may be subject to the risk of default, depending on the terms of such financing. If equity financing is available and obtained it may result in our shareholders experiencing significant dilution. If such financing is unavailable, we may be forced to curtail our operations, which may cause the value of our securities to decline in value and/or become worthless.

 

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We are subject to production declines and loss of revenue due to shut-in wells.

 

The majority of our production revenues come from a small number of producing wells. In the event those wells are required to be shut-in (as they were for various periods in the past), our production and revenue could be adversely effected. Our wells are shut-in from time-to-time for maintenance, workovers, upgrades and other matters outside of our control, including repairs, adverse weather (including hurricanes, flooding and tropical storms), inability to dispose of produced water or other regulatory and market conditions. Any significant period where our wells, and especially our top producing wells, are shut-in, would have a material adverse effect on our results of production, revenues and net income or loss for the applicable period.

Many of our leases are in areas that have been partially depleted or drained by offset wells.

Many of our leases are in areas that have been partially depleted or drained by offset drilling. Interference from offset drilling may inhibit our ability to find or recover commercial quantities of oil and/or may result in an acceleration in the decline in production of our wells, which may in turn have an adverse effect on our recovered barrels of oil and consequently our results of operations.

Crude oil and natural gas prices are highly volatile in general and low prices will negatively affect our financial results.

Our revenues, operating results, profitability, cash flow, future rate of growth and ability to borrow funds or obtain additional capital, as well as the carrying value of our oil and natural gas properties, are substantially dependent upon prevailing prices of crude oil and natural gas. Lower crude oil and natural gas prices also may reduce the amount of crude oil and natural gas that we can produce economically. Historically, the markets for crude oil and natural gas have been very volatile, and such markets are likely to continue to be volatile in the future. Prices for oil and natural gas fluctuate widely in response to a variety of factors beyond our control, such as:

overall U.S. and global economic conditions;
weather conditions and natural disasters;
seasonal variations in oil and natural gas prices;
price and availability of alternative fuels;
technological advances affecting oil and natural gas production and consumption;
consumer demand;
domestic and foreign supply of oil and natural gas;
variations in levels of production;
regional price differentials and quality differentials of oil and natural gas; price and quantity of foreign imports of oil, NGLs and natural gas;
the completion of large domestic or international exploration and production projects;
restrictions on exportation of our oil and natural gas;
the availability of refining capacity;
the impact of energy conservation efforts;
political conditions in or affecting other oil producing and natural gas producing countries, including the current conflicts in the Middle East and conditions in South America and Russia; and
domestic and foreign governmental regulations, actions and taxes.

Further, oil and natural gas prices do not necessarily fluctuate in direct relation to each other. Our revenue, profitability, and cash flow depend upon the prices of supply and demand for oil and natural gas, and a drop in prices can significantly affect our financial results and impede our growth. In particular, declines in commodity prices may:

negatively impact the value of our reserves, because declines in oil and natural gas prices would reduce the value and amount of oil and natural gas that we can produce economically;
reduce the amount of cash flow available for capital expenditures, repayment of indebtedness, and other corporate purposes; and
limit our ability to borrow money or raise additional capital.

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We may have difficulty managing growth in our business, which could have a material adverse effect on our business, financial condition and results of operations and our ability to execute our business plan in a timely fashion.

Because of our small size, growth in accordance with our business plans, if achieved, will place a significant strain on our financial, technical, operational and management resources. If we expand our activities, development and production, and increase the number of projects we are evaluating or in which we participate, there will be additional demands on our financial, technical and management resources. The failure to continue to upgrade our technical, administrative, operating and financial control systems or the occurrence of unexpected expansion difficulties, including the inability to recruit and retain experienced managers, geoscientists, petroleum engineers and landmen could have a material adverse effect on our business, financial condition and results of operations and our ability to execute our business plan in a timely fashion.

We face intense competition.

We are in direct competition for properties with numerous oil and natural gas companies, drilling and income programs and partnerships exploring various areas of Texas and Oklahoma. Many competitors are large, well-known energy companies, although no single entity dominates the industry. Many of our competitors possess greater financial and personnel resources enabling them to identify and acquire more economically desirable energy producing properties and drilling prospects than us. Additionally, there is competition from other fuel choices to supply the energy needs of consumers and industry. Management believes that a viable marketplace exists for smaller producers of natural gas and crude oil.

Our competitors may use superior technology and data resources that we may be unable to afford or that would require a costly investment by us in order to compete with them more effectively.

Our industry is subject to rapid and significant advancements in technology, including the introduction of new products and services using new technologies and databases. As our competitors use or develop new technologies, we may be placed at a competitive disadvantage, and competitive pressures may force us to implement new technologies at a substantial cost. In addition, many of our competitors will have greater financial, technical and personnel resources that allow them to enjoy technological advantages and may in the future allow them to implement new technologies before we can. We cannot be certain that we will be able to implement technologies on a timely basis or at a cost that is acceptable to us. One or more of the technologies that we will use or that we may implement in the future may become obsolete, and we may be adversely affected.

The future occurrence or continuance of an event of default under the IBC loan or the acceleration of amounts owed thereunder and/or under other of our debt agreements could have a material adverse effect on us and our financial condition.

The amounts owed to IBC include standard and customary events of default. Upon the occurrence of an event of default under the IBC loan (provided that as described above, we are in breach of certain terms and conditions of the IBC loan and IBC can, at any time, provide us a notice of the occurrence of an event of default thereunder), IBC may declare the entire unpaid balance (as well as any interest, fees and expenses) immediately due and payable under the IBC loan. Additionally, future debt agreements we enter into will likely have standard events of default, provided they may also have non-standard events of default. In the event of an occurrence of an event of default under our future debt agreements, the holder(s) thereof may declare the amounts due thereunder immediately due and payable. Funding to repay such amounts, if required, may not be available timely, on favorable terms, if at all, and if our creditors were to require immediate repayment of the amounts owed, it would likely have a material adverse effect on our results of operations, financial condition and the value of our common stock.

Restrictions on drilling activities intended to protect certain species of wildlife may adversely affect our ability to conduct drilling activities in some of the areas where we operate.

Oil and natural gas operations in our operating areas can be adversely affected by seasonal or permanent restrictions on drilling activities designed to protect various wildlife. Seasonal restrictions may limit our ability to operate in protected areas and can intensify competition for drilling rigs, oilfield equipment, services, supplies and qualified personnel, which may lead to periodic shortages when drilling is allowed. These constraints and the resulting shortages or high costs could delay our operations and materially increase our operating and capital costs. Permanent restrictions imposed to protect endangered species could prohibit drilling in certain areas or require the implementation of expensive mitigation measures. Specifically, applicable laws protecting endangered species prohibit the harming of endangered or threatened species, provide for habitat protection, and impose stringent penalties for noncompliance. The designation of previously unprotected species as threatened or endangered in areas where we operate could cause us to incur increased costs arising from species protection measures or could result in limitations, delays, or prohibitions on our exploration and production activities that could have an adverse impact on our ability to develop and produce our reserves.

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The derivatives legislation adopted by Congress, and implementation of that legislation by federal agencies, could have an adverse impact on our ability to hedge risks associated with our business.

On July 21, 2010, President Obama signed into law the Dodd-Frank Wall Street Reform and Consumer Protection Act, the Dodd-Frank Act, which, among other things, set forth a new framework for regulating certain derivative products including the commodity hedges of the type that we may elect to use, but many aspects of this law are subject to further rulemaking, will take effect over several years and are currently being challenged and/or rescinded by the current administration. As a result, it is difficult to anticipate the overall impact of the Dodd-Frank Act on our ability or willingness to enter into and maintain such commodity hedges and the terms of such hedges. There is a possibility that the Dodd-Frank Act could have a substantial and adverse impact on our ability to enter into and maintain these commodity hedges. In particular, the Dodd-Frank Act could result in the implementation of position limits and additional regulatory requirements on derivative arrangements, which could include new margin, reporting and clearing requirements. In addition, this legislation could have a substantial impact on our counterparties and may increase the cost of our derivative arrangements in the future. If these types of commodity hedges become unavailable or uneconomic, our commodity price risk could increase, which would increase the volatility of revenues and may decrease the amount of credit available to us. Any limitations or changes in our use of derivative arrangements could also materially affect our future ability to conduct acquisitions.

If we do not hedge our exposure to reductions in oil and natural gas prices, we may be subject to significant reductions in prices. Alternatively, we may use oil and natural gas price hedging contracts, which involve credit risk and may limit future revenues from price increases and result in significant fluctuations in our profitability.

In the event that we choose not to hedge our exposure to reductions in oil and natural gas prices by purchasing futures and by using other hedging strategies, we may be subject to significant reduction in prices which could have a material negative impact on our profitability. Alternatively, we may elect to use hedging transactions with respect to a portion of our oil and natural gas production to achieve more predictable cash flow and to reduce our exposure to price fluctuations. While the use of hedging transactions limits the downside risk of price declines, their use also may limit future revenues from price increases. Hedging transactions also involve the risk that the counterparty may be unable to satisfy its obligations.

Our operations are substantially dependent on the availability of water. Restrictions on our ability to obtain water may have an adverse effect on our financial condition, results of operations and cash flows.

Water is an essential component of deep shale oil and natural gas production during both the drilling and hydraulic fracturing, or fracking processes. Our operations and future operations could be adversely impacted if we are unable to locate sufficient amounts of water or dispose of or recycle water used in our exploration and production operations. Currently, the quantity of water required in certain completion operations, such as hydraulic fracturing, and changing regulations governing usage may lead to water constraints and supply concerns (particularly in some parts of the country). As a result, future availability of water from certain sources used in the past may be limited. Moreover, the imposition of new environmental initiatives and conditions could include restrictions on our ability to conduct certain operations such as hydraulic fracturing or disposal of waste, including, but not limited to, produced water, drilling fluids and other wastes associated with the exploration, development or production of oil and natural gas. The federal Clean Water Act, or CWA and analogous state laws impose restrictions and strict controls regarding the discharge of pollutants, including produced waters and other oil and natural gas waste, into navigable waters or other regulated federal and state waters. Permits or other approvals must be obtained to discharge pollutants to regulated waters and to conduct construction activities in such waters and wetlands. Uncertainty regarding regulatory jurisdiction over wetlands and other regulated waters has, and will continue to, complicate and increase the cost of obtaining such permits or other approvals. The CWA and analogous state laws provide for civil, criminal and administrative penalties for any unauthorized discharges of pollutants and unauthorized discharges of reportable quantities of oil and other hazardous substances. Many state discharge regulations, and the Federal National Pollutant Discharge Elimination System General permits issued by the EPA, prohibit the discharge of produced water and sand, drilling fluids, drill cuttings and certain other substances related to the oil and natural gas industry into coastal waters. While generally exempt under federal programs, many state agencies have also adopted regulations requiring certain oil and natural gas exploration and production facilities to obtain permits for storm water discharges. There has been recent nationwide concern over earthquakes associated with Class II underground injection control wells, a predominant storage method for crude oil and gas wastewater. It is likely that new rules and regulations will be developed to address these concerns, possibly eliminating access to Class II wells in certain locations, and increasing the cost of disposal in others. Finally, EPA studies have previously focused on various stages of water use in hydraulic fracturing operations. It is possible that, in the future, the EPA will move to more strictly regulate the use of water in hydraulic fracturing operations. While we cannot predict the impact that these changes may have on our business at this time, they may be material to our business, financial condition, and operations. Compliance with environmental regulations and permit requirements governing the withdrawal, storage and use of surface water or groundwater necessary for hydraulic fracturing of wells or the disposal or recycling of water will increase our operating costs and may cause delays, interruptions or termination of our operations, the extent of which cannot be predicted. In addition, our inability to meet our water supply needs to conduct our completion operations may impact our business, and any such future laws and regulations could negatively affect our financial condition, results of operations and cash flows.

 25 
 

We have significant amounts of outstanding debt and our operations may not be able to generate sufficient cash flows to meet our debt service obligations, which could reduce our financial flexibility, increase interest expenses and adversely impact our operations.

We currently have $35.9 million in outstanding debt, net of debt discount. Our ability to make payments on such indebtedness will depend on our ability to generate cash from our assets. We may not generate sufficient cash flow from operations to enable us to repay this indebtedness and to fund other liquidity needs, including capital expenditure requirements. Such indebtedness could affect our operations in several ways, including the following:

a significant portion of our cash flows are required to be used to service such indebtedness;
a high level of debt could increase our vulnerability to general adverse economic and industry conditions;
covenants contained in our agreements governing such outstanding indebtedness could limit our ability to borrow additional funds, dispose of assets, pay dividends and make certain investments;
a high level of debt may place us at a competitive disadvantage compared to our competitors that are less leveraged and, therefore, our competitors may be able to take advantage of opportunities that our indebtedness may prevent us from pursuing; and
debt covenants may affect our flexibility in planning for, and reacting to, changes in the economy and in our industry.

A high level of indebtedness increases the risk that we may default on our debt obligations. We may not be able to generate sufficient cash flows to pay the principal or interest on our debt. If we cannot service or refinance our indebtedness, we may have to take actions such as selling significant assets, seeking additional equity financing (which will result in additional dilution to stockholders) or reducing or delaying capital expenditures, any of which could have a material adverse effect on our operations and financial condition. If we do not have sufficient funds and are otherwise unable to arrange financing, our assets may be foreclosed upon which could have a material adverse effect on our business, financial condition and results of operations.

The shares of Series B Preferred Stock are convertible into shares of common stock and, when and if converted, will result in additional dilution to our current stockholders.

As of the date of this report, we have 408,508 outstanding shares of Series B Preferred Stock. Each share of Series B Preferred Stock is convertible, at the option of the holder, into that number of fully-paid, nonassessable shares of common stock determined by dividing the Original Issue Price for the Series B Preferred Stock ($25.00, as may be adjusted for recapitalizations) by the Conversion Price ($87.50, as may be adjusted for recapitalizations)(i.e., on a 0.2857-to-1 basis). Each share of Series B Preferred Stock will automatically convert into shares of common stock under certain conditions set forth in the Certificate of Designations of the Series B Preferred Stock. Assuming the conversion of all such shares, this would result in the issuance of 116,717 shares of our common stock.

 26 
 

Any weakness in internal control over financial reporting or disclosure controls and procedures could result in a loss of investor confidence in our financial reports and lead to a stock price decline.

We are required to evaluate our internal control over financial reporting under Section 404 of the Sarbanes-Oxley Act of 2002 and report the results in our annual report on Form 10-K, including this Annual Report on Form 10-K. We are also required to maintain effective disclosure controls and procedures. If material weaknesses arise and they are not remedied, we will be unable to assert that our internal controls are effective. Any failure to have effective internal control over financial reporting or disclosure controls and procedures could cause investors to lose confidence in the accuracy and completeness of our financial reports, limit our ability to raise financing or lead to regulatory sanctions, any of which could result in a material adverse effect on our business or decline in the market price of our common stock.

If we acquire crude oil and natural gas properties in the future, our failure to fully identify existing and potential problems, to accurately estimate reserves, production rates or costs, or to effectively integrate the acquired properties into our operations could materially and adversely affect our business, financial condition and results of operations.

From time to time, we seek to acquire crude oil and natural gas properties. Although we perform reviews of properties to be acquired in a manner that we believe is duly diligent and consistent with industry practices, reviews of records and properties may not necessarily reveal existing or potential problems, and may not permit us to become sufficiently familiar with the properties in order to fully assess their deficiencies and potential. Even when problems with a property are identified, we may assume environmental and other risks and liabilities in connection with acquired properties pursuant to the acquisition agreements. Moreover, there are numerous uncertainties inherent in estimating quantities of crude oil and natural gas reserves (as discussed further below), actual future production rates and associated costs with respect to acquired properties. Actual reserves, production rates and costs may vary substantially from those assumed in our estimates. We may be unable to locate or make suitable acquisitions on acceptable terms and future acquisitions may not be effectively and profitably integrated. Acquisitions involve risks that could divert management resources and/or result in the possible loss of key employees and customers of the acquired operations. For the reasons above, among others, an acquisition may have a material and adverse effect on our business and results of operations, particularly during the periods in which the operations of the acquired properties are being integrated into our ongoing operations or if we are unable to effectively integrate the acquired properties into our ongoing operations.

If we make any acquisitions or enter into any business combinations in the future, they may disrupt or have a negative impact on our business.

If we make acquisitions or enter into any business combinations in the future, funding permitting, we could have difficulty integrating the acquired companies’ assets, personnel and operations with our own. Additionally, acquisitions, mergers or business combinations we may enter into in the future could result in a change of control of the Company, and a change in the Board of Directors or officers of the Company. In addition, the key personnel of the acquired business may not be willing to work for us. We cannot predict the effect expansion may have on our core business. Regardless of whether we are successful in making an acquisition or completing a business combination, the negotiations could disrupt our ongoing business, distract our management and employees and increase our expenses. In addition to the risks described above, acquisitions and business combinations are accompanied by a number of inherent risks, including, without limitation, the following:

the difficulty of integrating acquired companies, concepts and operations;
the potential disruption of the ongoing businesses and distraction of our management and the management of acquired companies;
change in our business focus and/or management;
difficulties in maintaining uniform standards, controls, procedures and policies;
the potential impairment of relationships with employees and partners as a result of any integration of new management personnel;
the potential inability to manage an increased number of locations and employees;
our ability to successfully manage the companies and/or concepts acquired;
the failure to realize efficiencies, synergies and cost savings; or
the effect of any government regulations which relate to the business acquired.

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Our business could be severely impaired if and to the extent that we are unable to succeed in addressing any of these risks or other problems encountered in connection with an acquisition or business combination, many of which cannot be presently identified. These risks and problems could disrupt our ongoing business, distract our management and employees, increase our expenses and adversely affect our results of operations.

Any acquisition or business combination transaction we enter into in the future could cause substantial dilution to existing stockholders, result in one party having majority or significant control over the Company or result in a change in business focus of the Company.

We depend significantly upon the continued involvement of our present management.

We depend to a significant degree upon the involvement of our management, specifically, our newly appointed Interim Chief Executive Officer, Louis G. Schott, who is in charge of our strategic planning and operations, and our Chief Financial Officer, Robert Schleizer. Our performance and success are dependent to a large extent on the efforts and continued employment of Mr. Schott and Mr. Schleizer. We do not believe that Mr. Schott or Mr. Schleizer could be quickly replaced with personnel of equal experience and capabilities, and their successor(s) may not be as effective. If Mr. Schott, Mr. Schleizer, or any of our other key personnel resign or become unable to continue in their present roles and if they are not adequately replaced, our business operations could be adversely affected.

We have an active Board of Directors that meets several times throughout the year and is intimately involved in our business and the determination of our operational strategies. Members of our Board of Directors work closely with management to identify potential prospects, acquisitions and areas for further development. If any of our directors resign or become unable to continue in their present role, it may be difficult to find replacements with the same knowledge and experience and as a result, our operations may be adversely affected.

Certain of our undeveloped leasehold assets are subject to leases that will expire over the next several years unless production is established on units containing the acreage.

Leases on natural gas and oil properties typically have a term of three to five years, after which they expire unless, prior to expiration, a well is drilled and production of hydrocarbons in paying quantities is established. If our leases expire and we are unable to renew the leases, we will lose our right to develop the related properties. Although we seek to actively manage our undeveloped properties, our drilling plans for these areas are subject to change based upon various factors, including drilling results, natural gas and oil prices, the availability and cost of capital, drilling and production costs, availability of drilling services and equipment, gathering system and pipeline transportation constraints and regulatory approvals.

Our business is subject to extensive regulation.

As many of our activities are subject to federal, state and local regulation, and as these rules are subject to constant change or amendment, our operations may be adversely affected by new or different government regulations, laws or court decisions applicable to our operations.

Government regulation and liability for environmental matters may adversely affect our business and results of operations.

Crude oil and natural gas operations are subject to extensive federal, state and local government regulations, which may be changed from time to time. Matters subject to regulation include discharge permits for drilling operations, drilling bonds, reports concerning operations, the spacing of wells, unitization and pooling of properties and taxation. From time to time, regulatory agencies have imposed price controls and limitations on production by restricting the rate of flow of crude oil and natural gas wells below actual production capacity in order to conserve supplies of crude oil and natural gas. There are federal, state and local laws and regulations primarily relating to protection of human health and the environment applicable to the development, production, handling, storage, transportation and disposal of crude oil and natural gas, byproducts thereof and other substances and materials produced or used in connection with crude oil and natural gas operations. In addition, we may inherit liability for environmental damages caused by previous owners of property we purchase or lease. As a result, we may incur substantial liabilities to third parties or governmental entities. The implementation of new, or the modification of existing, laws or regulations could have a material adverse effect on us.

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Future increases in our tax obligations; either due to increases in taxes on energy products, energy service companies and exploration activities or reductions in currently available federal income tax deductions with respect to oil and natural gas exploration and development, may adversely affect our results of operations and increase our operating expenses.

Federal, state and local governments have jurisdiction in areas where we operate and impose taxes on the oil and natural gas products we sell. There are constant discussions by federal, state and local officials concerning a variety of energy tax proposals, some of which, if passed, would add or increase taxes on energy products, service companies and exploration activities. The passage of any legislation or any other changes in U.S. federal income tax laws could impact or increase the taxes that we are required to pay and consequently adversely affect our results of operations and/or increase our operating expenses.

The crude oil and natural gas reserves we report in our SEC filings are estimates and may prove to be inaccurate.

There are numerous uncertainties inherent in estimating crude oil and natural gas reserves and their estimated values. The reserves we report in our filings with the SEC now and in the future will only be estimates and such estimates may prove to be inaccurate because of these uncertainties. Reservoir engineering is a subjective and inexact process of estimating underground accumulations of crude oil and natural gas that cannot be measured in an exact manner. Estimates of economically recoverable crude oil and natural gas reserves depend upon a number of variable factors, such as historical production from the area compared with production from other producing areas and assumptions concerning effects of regulations by governmental agencies, future crude oil and natural gas prices, future operating costs, severance and excise taxes, development costs and work-over and remedial costs. Some or all of these assumptions may in fact vary considerably from actual results. For these reasons, estimates of the economically recoverable quantities of crude oil and natural gas attributable to any particular group of properties, classifications of such reserves based on risk of recovery, and estimates of the future net cash flows expected therefrom prepared by different engineers or by the same engineers but at different times may vary substantially. Accordingly, reserve estimates may be subject to downward or upward adjustment. Actual production, revenue and expenditures with respect to our reserves will likely vary from estimates, and such variances may be material.

Additionally, “probable” and “possible reserve estimates” are considered unproved reserves and as such, the SEC views such estimates to be inherently unreliable, may be misunderstood or seen as misleading to investors that are not “experts” in the oil or natural gas industry. Unless you have such expertise, you should not place undue reliance on these estimates. Except as required by applicable law, we undertake no duty to update this information and do not intend to update this information.

The calculated present value of future net revenues from our proved reserves will not necessarily be the same as the current market value of our estimated oil and natural gas reserves.

You should not assume that the present value of future net cash flows as included in our public filings is the current market value of our estimated proved oil and natural gas reserves. We generally base the estimated discounted future net cash flows from proved reserves on current costs held constant over time without escalation and on commodity prices using an unweighted arithmetic average of first-day-of-the-month index prices, appropriately adjusted, for the 12-month period immediately preceding the date of the estimate. Actual future prices and costs may be materially higher or lower than the prices and costs used for these estimates and will be affected by factors such as:

actual prices we receive for oil and natural gas;
actual cost and timing of development and production expenditures;
the amount and timing of actual production; and
changes in governmental regulations or taxation.

 

In addition, the 10% discount factor that is required to be used to calculate discounted future net revenues for reporting purposes under GAAP is not necessarily the most appropriate discount factor based on the cost of capital in effect from time to time and risks associated with our business and the oil and natural gas industry in general.

 

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Crude oil and natural gas development, re-completion of wells from one reservoir to another reservoir, restoring wells to production and exploration, drilling and completing new wells are speculative activities and involve numerous risks and substantial and uncertain costs.

Our growth will be materially dependent upon the success of our future development program. Even considering our business philosophy to avoid wildcat wells, drilling for crude oil and natural gas and reworking existing wells involves numerous risks, including the risk that no commercially productive crude oil or natural gas reservoirs will be encountered. The cost of exploration, drilling, completing and operating wells is substantial and uncertain, and drilling operations may be curtailed, delayed or cancelled as a result of a variety of factors beyond our control, including: unexpected drilling conditions; pressure or irregularities in formations; equipment failures or accidents; inability to obtain leases on economic terms, where applicable; adverse weather conditions and natural disasters; compliance with governmental requirements; and shortages or delays in the availability of drilling rigs or crews and the delivery of equipment. Furthermore, we cannot provide investors with any assurance that we will be able to obtain rights to additional producing properties in the future and/or that any properties we obtain rights to will contain commercially exploitable quantities of oil and/or gas.

Drilling or reworking is a highly speculative activity. Even when fully and correctly utilized, modern well completion techniques such as hydraulic fracturing and horizontal drilling do not guarantee that we will find crude oil and/or natural gas in our wells. Hydraulic fracturing involves pumping a fluid with or without particulates into a formation at high pressure, thereby creating fractures in the rock and leaving the particulates in the fractures to ensure that the fractures remain open, thereby potentially increasing the ability of the reservoir to produce oil or natural gas. Horizontal drilling involves drilling horizontally out from an existing vertical well bore, thereby potentially increasing the area and reach of the well bore that is in contact with the reservoir. Our future drilling activities may not be successful and, if unsuccessful, such failure would have an adverse effect on our future results of operations and financial condition. Our overall drilling success rate and/or our drilling success rate for activities within a particular geographic area may decline in the future. We may identify and develop prospects through a number of methods, some of which do not include lateral drilling or hydraulic fracturing, and some of which may be unproven. The drilling and results for these prospects may be particularly uncertain. Our drilling schedule may vary from our capital budget. The final determination with respect to the drilling of any scheduled or budgeted prospects will be dependent on a number of factors, including, but not limited to: the results of previous development efforts and the acquisition, review and analysis of data; the availability of sufficient capital resources to us and the other participants, if any, for the drilling of the prospects; the approval of the prospects by other participants, if any, after additional data has been compiled; economic and industry conditions at the time of drilling, including prevailing and anticipated prices for crude oil and natural gas and the availability of drilling rigs and crews; our financial resources and results; the availability of leases and permits on reasonable terms for the prospects; and the success of our drilling technology.

These projects may not be successfully developed and the wells discussed, if drilled, may not encounter reservoirs of commercially productive crude oil or natural gas. There are numerous uncertainties in estimating quantities of proved reserves, including many factors beyond our control. If we are unable to find commercially exploitable quantities of oil and natural gas in any properties we may acquire in the future, and/or we are unable to commercially extract such quantities we may find in any properties we may acquire in the future, the value of our securities may decline in value.

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Commodity price declines during 2016 and 2017 resulted in impairment of our oil and gas properties through the year ended March 2017, and future natural gas and oil price declines could result in additional write-downs of the carrying amount of our assets, which could materially and adversely affect our results of operations.

The value of our assets depends on prices of natural gas and oil. Declines in these prices as well as increases in development costs, changes in well performance, delays in asset development or deterioration of drilling results may result in our having to make material downward adjustments to our estimated proved reserves, and could result in an impairment charge and a corresponding write-down of the carrying amount of our oil and natural gas properties. During the year ended March 31, 2017, the Company recorded impairments totaling $79.1 million, which represented $10.9 million related to proved properties, $18.7 million related to unproved properties, and $49.5 million in conjunction with the Acquisition, primarily due to continued low commodity prices during the fiscal year. During the year ended March 31, 2018, commodity prices for natural gas and oil stemmed the need for significant impairments and the only impairments recorded related to the expiration of leasehold costs ($8 million) and proved properties ($0.1 million).

We evaluate our oil and gas properties for impairment using the full cost method whereby the carrying value of property and equipment is compared to the “estimated present value” of its proved reserves discounted at a 10-percent interest rate of future net revenues, based on current economic and operating conditions at the end of the period, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences. In the event that commodity prices decline further, there could be a significant revision in the future.

Because of the inherent dangers involved in oil and gas exploration, there is a risk that we may incur liability or damages as we conduct our business operations, which could force us to expend a substantial amount of money in connection with litigation and/or a settlement.

The oil and natural gas business involves a variety of operating hazards and risks such as well blowouts, pipe failures, casing collapse, explosions, uncontrollable flows of oil, natural gas or well fluids, fires, spills, pollution, releases of toxic gas and other environmental hazards and risks. These hazards and risks could result in substantial losses to us from, among other things, injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, cleanup responsibilities, regulatory investigation and penalties and suspension of operations. In addition, we may be liable for environmental damages caused by previous owners of property purchased and leased by us in the future. As a result, substantial liabilities to third parties or governmental entities may be incurred, the payment of which could reduce or eliminate the funds available for the purchase of properties and/or property interests, exploration, development or acquisitions or result in the loss of our properties and/or force us to expend substantial monies in connection with litigation or settlements. As such, our current insurance or the insurance that we obtain in the future may not be adequate to cover any losses or liabilities. We cannot predict the availability of insurance or the availability of insurance at premium levels that justify our purchase. The occurrence of a significant event not fully insured or indemnified against could materially and adversely affect our financial condition and operations. We may elect to self-insure if management believes that the cost of insurance, although available, is excessive relative to the risks presented. In addition, pollution and environmental risks generally are not fully insurable. The occurrence of an event not fully covered by insurance could have a material adverse effect on our financial condition and results of operations, which could lead to any investment in us declining in value or becoming worthless.

Unless we replace our oil and natural gas reserves, our reserves and production will decline, which would adversely affect our business, financial condition and results of operations.

The rate of production from our oil and natural gas properties will decline as our reserves are depleted. Our future oil and natural gas reserves and production and, therefore, our income and cash flow, are highly dependent on our success in (a) efficiently developing and exploiting our current reserves on properties owned by us or by other persons or entities and (b) economically finding or acquiring additional oil and natural gas properties. In the future, we may have difficulty acquiring new properties. During periods of low oil and/or natural gas prices, it will become more difficult to raise the capital necessary to finance expansion activities. If we are unable to replace our production, our reserves will decrease, and our business, financial condition and results of operations would be adversely affected.

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The unavailability or high cost of drilling rigs, completion equipment and services, supplies and personnel, including hydraulic fracturing equipment and personnel, could adversely affect our ability to establish and execute exploration and development plans within budget and on a timely basis, which could have a material adverse effect on our business, financial condition and results of operations.

Shortages or the high cost of drilling rigs, completion equipment and services, supplies or personnel could delay or adversely affect our operations. When drilling activity in the United States increases, associated costs typically also increase, including those costs related to drilling rigs, equipment, supplies and personnel and the services and products of other vendors to the industry. These costs may increase, and necessary equipment and services may become unavailable to us at economical prices. Should this increase in costs occur, we may delay drilling activities, which may limit our ability to establish and replace reserves, or we may incur these higher costs, which may negatively affect our business, financial condition and results of operations.

We incur certain costs to comply with government regulations, particularly regulations relating to environmental protection and safety, and could incur even greater costs in the future.

Our exploration, production and marketing operations are regulated extensively at the federal, state and local levels and are subject to interruption or termination by governmental and regulatory authorities based on environmental or other considerations. Moreover, we have incurred and will continue to incur costs in our efforts to comply with the requirements of environmental, safety and other regulations. Further, the regulatory environment in the oil and natural gas industry could change in ways that we cannot predict and that might substantially increase our costs of compliance and, in turn, materially and adversely affect our business, results of operations and financial condition.

Specifically, as an owner or lessee and operator of crude oil and natural gas properties, we are subject to various federal, state, local and foreign regulations relating to the discharge of materials into, and the protection of, the environment. These regulations may, among other things, impose liability on us for the cost of pollution cleanup resulting from operations, subject us to liability for pollution damages and require suspension or cessation of operations in affected areas. Moreover, we are subject to the United States (“U.S.”) EPA rule requiring annual reporting of greenhouse gas (“GHG”) emissions. Changes in, or additions to, these regulations could lead to increased operating and compliance costs and, in turn, materially and adversely affect our business, results of operations and financial condition.

We are aware of the increasing focus of local, state, national and international regulatory bodies on GHG emissions and climate change issues. In addition to the U.S. EPA’s rule requiring annual reporting of GHG emissions, we are also aware of legislation proposed by U.S. lawmakers to reduce GHG emissions.

Additionally, there have been various proposals to regulate hydraulic fracturing at the federal level, including possible regulations limiting the ability to dispose of produced waters. Currently, the regulation of hydraulic fracturing is primarily conducted at the state level through permitting and other compliance requirements. Any new federal regulations that may be imposed on hydraulic fracturing could result in additional permitting and disclosure requirements (such as the reporting and public disclosure of the chemical additives used in the fracturing process) and in additional operating restrictions. In addition to the possible federal regulation of hydraulic fracturing, some states and local governments have considered imposing various conditions and restrictions on drilling and completion operations, including requirements regarding casing and cementing of wells, testing of nearby water wells, restrictions on the access to and usage of water and restrictions on the type of chemical additives that may be used in hydraulic fracturing operations. Such federal and state permitting and disclosure requirements and operating restrictions and conditions could lead to operational delays and increased operating and compliance costs and, moreover, could delay or effectively prevent the development of crude oil and natural gas from formations which would not be economically viable without the use of hydraulic fracturing.

We will continue to monitor and assess any new policies, legislation, regulations and treaties in the areas where we operate to determine the impact on our operations and take appropriate actions, where necessary. We are unable to predict the timing, scope and effect of any currently proposed or future laws, regulations or treaties, but the direct and indirect costs of such laws, regulations and treaties (if enacted) could materially and adversely affect our business, results of operations and financial condition.

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Federal and state legislation and regulatory initiatives relating to hydraulic fracturing could result in increased costs and additional operating restrictions or delays.

Hydraulic fracturing is a common practice that is used to stimulate production of hydrocarbons from tight formations. The process involves the injection of water, sand and chemicals under pressure into rock formations to fracture the surrounding rock and stimulate production. There has been increasing public controversy regarding hydraulic fracturing with regard to the transportation and use of fracturing fluids, impacts on drinking water supplies, use of waters, and the potential for impacts to surface water, groundwater, air quality and the environment generally. A number of lawsuits and enforcement actions have been initiated implicating hydraulic fracturing practices. Additional legislation or regulation could make it more difficult to perform hydraulic fracturing, cause operational delays, increase our operating costs or make it easier for third parties opposing the hydraulic fracturing process to initiate legal proceedings. New legislation or regulations in the future could have the effect of prohibiting the use of hydraulic fracturing, which would prevent us from completing our wells as planned and would have a material adverse effect on production from our wells. If these legislative and regulatory initiatives cause a material delay or decrease in our drilling or hydraulic fracturing activities, our business and profitability could be materially impacted.

Possible regulation related to global warming and climate change could have an adverse effect on our operations and demand for oil and gas.

Studies over recent years have indicated that emissions of certain gases may be contributing to warming of the Earth’s atmosphere. In response to these studies, governments have begun adopting domestic and international climate change regulations that require reporting and reductions of the emission of greenhouse gases. Methane, a primary component of natural gas, and carbon dioxide, a by-product of the burning of oil, natural gas and refined petroleum products, are considered greenhouse gases. In the United States, at the state level, many states, either individually or through multi-state regional initiatives, have begun implementing legal measures to reduce emissions of greenhouse gases, primarily through the planned development of emission inventories or regional greenhouse gas cap and trade programs or have begun considering adopting greenhouse gas regulatory programs. At the federal level, Congress has considered legislation that could establish a cap and trade system for restricting greenhouse gas emissions in the United States. The ultimate outcome of this federal legislative initiative remains uncertain. In addition to pending climate legislation, the EPA has issued greenhouse gas monitoring and reporting regulations. Beyond measuring and reporting, the EPA issued an “Endangerment Finding” under section 202(a) of the Clean Air Act, concluding that greenhouse gas pollution threatens the public health and welfare of current and future generations. The finding served as a first step to issuing regulations that require permits for and reductions in greenhouse gas emissions for certain facilities. Moreover, the EPA has begun regulating greenhouse gas emission from certain facilities pursuant to the Prevention of Significant Deterioration and Title V provisions of the Clean Air Act. In the courts, several decisions have been issued that may increase the risk of claims being filed by government entities and private parties against companies that have significant greenhouse gas emissions. Such cases may seek to challenge air emissions permits that greenhouse gas emitters apply for and seek to force emitters to reduce their emissions or seek damages for alleged climate change impacts to the environment, people, and property. Any existing or future laws or regulations that restrict or reduce emissions of greenhouse gases could require us to incur increased operating and compliance costs. In addition, such laws and regulations may adversely affect demand for the fossil fuels we produce, including by increasing the cost of combusting fossil fuels and by creating incentives for the use of alternative fuels and energy.

The lack of availability or high cost of drilling rigs, equipment, supplies, insurance, personnel and oilfield services could adversely affect our ability to execute our exploration and development plans on a timely basis and within our budget.

Our industry is cyclical and, from time to time, there is a shortage of drilling rigs, equipment, supplies or qualified personnel. During these periods, the costs and delivery times of rigs, equipment and supplies tend to increase, in some cases substantially. In addition, the demand for, and wage rates of, qualified drilling rig crews rise as the number of active rigs in service increases within a geographic area. If increasing levels of exploration and production result in response to strong prices of oil and natural gas, the demand for oilfield services will likely rise, and the costs of these services will likely increase, while the quality of these services may suffer. The future lack of availability or high cost of drilling rigs, as well as any future lack of availability or high costs of other equipment, supplies, insurance or qualified personnel, in the areas in which we operate could materially and adversely affect our business and results of operations.

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Our officers and directors have limited liability, and we are required in certain instances to indemnify our officers and directors for breaches of their fiduciary duties.

We have adopted provisions in our Articles of Incorporation and Bylaws which limit the liability of our officers and directors and provide for indemnification by us of our officers and directors to the full extent permitted by Nevada corporate law. Our articles generally provide that our officers and directors shall have no personal liability to us or our stockholders for monetary damages for breaches of their fiduciary duties as directors, except for breaches of their duties of loyalty, acts or omissions not in good faith or which involve intentional misconduct or knowing violation of law, acts involving unlawful payment of dividends or unlawful stock purchases or redemptions, or any transaction from which a director derives an improper personal benefit. Such provisions substantially limit our stockholders’ ability to hold officers and directors liable for breaches of fiduciary duty, and may require us to indemnify our officers and directors.

We currently have outstanding indebtedness and we may incur additional indebtedness which could reduce our financial flexibility, increase interest expense and adversely impact our operations and our unit costs.

We currently have outstanding indebtedness and in the future, we may incur significant amounts of additional indebtedness in order to make acquisitions or to develop our properties. Our level of indebtedness could affect our operations in several ways, including the following:

a significant portion of our cash flows could be used to service our indebtedness;
a high level of debt would increase our vulnerability to general adverse economic and industry conditions;
any covenants contained in the agreements governing our outstanding indebtedness could limit our ability to borrow additional funds;
dispose of assets, pay dividends and make certain investments;
a high level of debt may place us at a competitive disadvantage compared to our competitors that are less leveraged and, therefore, may be able to take advantage of opportunities that our indebtedness may prevent us from pursuing; and
debt covenants to which we may agree may affect our flexibility in planning for, and reacting to, changes in the economy and in our industry.

A high level of indebtedness increases the risk that we may default on our debt obligations. We may not be able to generate sufficient cash flows to pay the principal or interest on our debt, and future working capital, borrowings or equity financing may not be available to pay or refinance such debt. If we do not have sufficient funds and are otherwise unable to arrange financing, we may have to sell significant assets or have a portion of our assets foreclosed upon which could have a material adverse effect on our business, financial condition and results of operations.

Our properties are located in Texas and Oklahoma, making us vulnerable to risks associated with operating in one major geographic area.

All of our properties are located in Texas and Oklahoma. As a result, we may be disproportionately exposed to the impact of delays or interruptions of production from wells caused by transportation capacity constraints, curtailment of production, availability of equipment, facilities, personnel or services, significant governmental regulation, natural disasters, adverse weather conditions, or interruption of transportation of oil or natural gas produced from the wells in this area. In addition, the effect of fluctuations on supply and demand may become more pronounced within specific geographic oil and gas producing areas such as the ones we operate in, which may cause these conditions to occur with greater frequency or magnify the effect of these conditions. Due to the concentrated nature of our portfolio, a number of our properties could experience any of the same conditions at the same time, resulting in a relatively greater impact on our results of operations than they might have on other companies that have a more diversified portfolio of properties. Such delays or interruptions could have a material adverse effect on our financial condition and results of operations.

Servicing our debt requires a significant amount of cash, which we may not have available when payments are due.

Our ability to make scheduled payments of the principal of, to pay interest on or to refinance our indebtedness, will depend upon our future operating performance, which is subject to general economic and competitive conditions and to financial, business and other factors, many of which we cannot control. In the future, we may incur additional indebtedness in order to make future acquisitions or to develop our properties, including under our current liabilities. If we do not have sufficient funds on hand to pay our debt, we may be required to seek a waiver or amendment from our lenders, refinance our indebtedness, sell assets or sell additional securities. Our ability to refinance our indebtedness will depend on the capital markets and our financial condition at the time. We may not be able obtain such financing or complete such transactions on terms acceptable to us, or at all. In addition, we may not be able to consummate an asset sale to raise capital or sell assets at prices that we believe are fair, and proceeds that we do receive may not be adequate to meet any debt service obligations then due. Our failure to generate sufficient funds to pay our debts or to undertake any of these actions successfully could result in a default on our debt obligations, which would materially adversely affect our business, results of operations and financial condition.

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Future acquired properties may not be worth what we pay due to uncertainties in evaluating recoverable reserves and other expected benefits, as well as potential liabilities.

Successful property acquisitions require an assessment of a number of factors beyond our control. These factors include estimates of recoverable reserves, exploration potential, future natural gas and oil prices, operating costs, production taxes and potential environmental and other liabilities. These assessments are complex and inherently imprecise. Our review of the properties we acquire may not reveal all existing or potential problems. In addition, our review may not allow us to fully assess the potential deficiencies of the properties. We do not inspect every well, and even when we inspect a well we may not discover structural, subsurface, or environmental problems that may exist or arise. There may be threatened or contemplated claims against the assets or businesses we acquire related to environmental, title, regulatory, tax, contract, litigation or other matters of which we are unaware, which could materially and adversely affect our production, revenues and results of operations. We may not be entitled to contractual indemnification for pre-closing liabilities, including environmental liabilities, and our contractual indemnification may not be effective. At times, we acquire interests in properties on an “as is” basis with limited representations and warranties and limited remedies for breaches of such representations and warranties. In addition, significant acquisitions can change the nature of our operations and business if the acquired properties have substantially different operating and geological characteristics or are in different geographic locations than our existing properties.

We have limited control over activities in properties we do not operate, which could reduce our production and revenues, affect the timing and amounts of capital requirements and potentially result in a dilution of our respective ownership interest in the event we are unable to make any required capital contributions.

We do not operate all of the properties in which we have an interest. As a result, we may have a limited ability to exercise influence over normal operating procedures, expenditures or future development of underlying properties and their associated costs. For all of the properties that are operated by others, we are dependent on their decision-making with respect to day-to-day operations over which we have little control. The failure of an operator of wells in which we have an interest to adequately perform operations, or an operator’s breach of applicable agreements, could reduce production and revenues we receive from that well. The success and timing of our drilling and development activities on properties operated by others depend upon a number of factors outside of our control, including the timing and amount of capital expenditures, the available expertise and financial resources, the inclusion of other participants and the use of technology. Since we do not own the majority interest in many of the wells we do not operate, we may not be in a position to remove the operator in the event of poor performance.

Risks Relating To An Investment In Our Securities

We are not currently in compliance with NYSE American continued listing standards and if we are unable to maintain compliance with NYSE American continued listing standards, our common stock may be delisted from the NYSE American equities market, which would likely cause the liquidity and market price of our common stock to decline.

 

Our common stock is currently listed on the NYSE American. The NYSE American will consider suspending dealings in, or delisting, securities of an issuer that does not meet its continued listing standards. If we cannot meet the NYSE American continued listing requirements, the NYSE American may delist our common stock, which could have an adverse impact on us and the liquidity and market price of our stock.

 

We may be unable to comply with NYSE American continued listing standards. Our business has been and may continue to be affected by worldwide macroeconomic factors, which include uncertainties in the credit and capital markets. External factors that affect our stock price, such as liquidity requirements of our investors, as well as our performance, could impact our market capitalization, revenue and operating results, which, in turn, could affect our ability to comply with the NYSE American’s listing standards. The NYSE American has the ability to suspend trading in our common stock or remove our common stock from listing on the NYSE American if in the opinion of the exchange: (a) the financial condition and/or operating results of the Company appear to be unsatisfactory; or (b) it appears that the extent of public distribution or the aggregate market value of our common stock has become so reduced as to make further dealings on the exchange inadvisable; or (c) we have sold or otherwise disposed of our principal operating assets, or have ceased to be an operating company; or (d) we have failed to comply with our listing agreements with the exchange (which include that we receive additional listing approval from the exchange prior to us issuing any shares of common stock, something we have inadvertently failed to comply with in the past); or (e) any other event shall occur or any condition shall exist which makes further dealings on the exchange unwarranted.

 

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On August 3, 2017, we received notice from the NYSE American that the Company is not in compliance with Sections 1003(a)(i) through (iii) of the NYSE American Company Guide in that we reported a stockholders’ deficit of $10.6 million as of March 31, 2017 and net losses in our five most recent fiscal years then ended, meaning that we (i) had stockholders’ equity of less than $2,000,000 and sustained losses from continuing operations and/or net losses in two of our three most recent fiscal years; (ii) had stockholders’ equity of less than $4,000,000 and sustained losses from continuing operations and/or net losses in three of our four most recent fiscal years; and (iii) had stockholders’ equity of less than $6,000,000 and sustained losses from continuing operations and/or net losses in our five most recent fiscal years. In order to maintain our listing on the Exchange, the Exchange had requested that the Company submit a plan of compliance by September 5, 2017 addressing how the Company intends to regain compliance with Sections 1003(a)(i), (ii) and (iii) of the Company Guide by August 3, 2018. The Exchange extended the date to submit a plan to September 20, 2017 and the plan was submitted timely by the extended deadline.

 

On October 5, 2017, we received an additional notification from the Exchange that our securities had been selling for a low price per share for a substantial period of time and that the Company’s common stock had a 30-day average price below $0.20 as of October 5, 2017. Pursuant to Section 1003(f)(v) of the NYSE American Company Guide, the NYSE American staff determined that the Company’s continued listing was predicated on it effecting a reverse stock split of its common stock or otherwise demonstrating sustained price improvement within a reasonable period of time, which the staff determined to be until April 5, 2018. Effective on March 5, 2018, we affected a 1-for-25 reverse stock split of our outstanding common stock which satisfied the NYSE American’s continued listing requirements as to the trading price of our common stock.

 

On November 3, 2017, the Company was notified that the Exchange accepted the Company’s plan to regain compliance with the Exchange’s continued listing standards set forth in Sections 1003(a)(i), (ii) and (iii) of the Company Guide by August 3, 2018, subject to periodic review by the Exchange for compliance with the initiatives set forth in the plan. If the Company is not in compliance with the continued listing standards by August 3, 2018, or if the Company does not make progress consistent with the plan during the plan period, the NYSE Regulation staff may initiate delisting proceedings as appropriate.

 

Additionally, on November 7, 2017, the Company was notified by the Exchange that it was back in compliance with the separate continued listing deficiency relating to non-compliance with Sections 134 and 1101 of the Company Guide, which previously announced deficiency was due to the fact that the Company did not timely file its Quarterly Report on Form 10-Q for the quarter ended June 30, 2017, which report was filed on November 6, 2017.

 

If we are unable to retain compliance with the NYSE American criteria for continued listing, our common stock would be subject to delisting. A delisting of our common stock could negatively impact us by, among other things, reducing the liquidity and market price of our common stock and reducing the number of investors willing to hold or acquire our common stock, which could negatively impact our ability to raise equity financing. In addition, delisting from the NYSE American might negatively impact our reputation and, as a consequence, our business. Additionally, if we were delisted from the NYSE American and we are not able to list our common stock on another national exchange we will no longer be eligible to use Form S-3 registration statements (which we are currently unable to use due to the late filing described above and our ongoing defaults with IBC Bank) and will instead be required to file a Form S-1 registration statement for any primary or secondary offerings of our common stock, which would delay our ability to raise funds in the future, may limit the type of offerings of common stock we could undertake, and would increase the expenses of any offering, as, among other things, registration statements on Form S-1 are subject to SEC review and comments whereas take downs pursuant to a previously filed Form S-3 are not.

 

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If we are delisted from the NYSE American, your ability to sell your shares of our common stock would also be limited by the penny stock restrictions, which could further limit the marketability of your shares.

If our common stock is delisted from the NYSE American, it would come within the definition of “penny stock” as defined in the Exchange Act and would be covered by Rule 15g-9 of the Exchange Act. That Rule imposes additional sales practice requirements on broker-dealers who sell securities to persons other than established customers and accredited investors. For transactions covered by Rule 15g-9, the broker-dealer must make a special suitability determination for the purchaser and receive the purchaser’s written agreement to the transaction prior to the sale. Consequently, Rule 15g-9, if it were to become applicable, would affect the ability or willingness of broker-dealers to sell our securities, and accordingly would affect the ability of stockholders to sell their securities in the public market. These additional procedures could also limit our ability to raise additional capital in the future.

We do not intend to pay cash dividends to our stockholders.

We currently anticipate that we will retain all future earnings, if any, to finance the growth and development of our business. We do not intend to pay cash dividends in the foreseeable future. Any payment of cash dividends will depend upon our financial condition, capital requirements, earnings and other factors deemed relevant by our Board of Directors. As a result, only appreciation of the price of our common stock, which may not occur, will provide a return to our stockholders.

We currently have an illiquid and volatile market for our common stock, and the market for our common stock is and may remain illiquid and volatile in the future.

We currently have a highly sporadic, illiquid and volatile market for our common stock, which market is anticipated to remain sporadic, illiquid and volatile in the future. Factors that could affect our stock price or result in fluctuations in the market price or trading volume of our common stock include:

our actual or anticipated operating and financial performance and drilling locations, including reserve estimates;
quarterly variations in the rate of growth of our financial indicators, such as net income/loss per share, net income/loss and cash flows, or those of companies that are perceived to be similar to us;
changes in revenue, cash flows or earnings estimates or publication of reports by equity research analysts;
speculation in the press or investment community;
public reaction to our press releases, announcements and filings with the SEC;
sales of our common stock by us or other stockholders, or the perception that such sales may occur;
the amount of our freely tradable common stock available in the public marketplace;
general financial market conditions and oil and natural gas industry market conditions, including fluctuations in commodity prices;
the realization of any of the risk factors that we are subject to;
the recruitment or departure of key personnel;
commencement of, or involvement in, litigation;
the prices of oil and natural gas;
the success of our exploration and development operations, and the marketing of any oil and natural gas we produce;
changes in market valuations of companies similar to ours; and
domestic and international economic, legal and regulatory factors unrelated to our performance.

Our common stock is listed on the NYSE American under the symbol “CEI.” Our stock price may be impacted by factors that are unrelated or disproportionate to our operating performance. The stock markets in general have experienced extreme volatility that has often been unrelated to the operating performance of particular companies. These broad market fluctuations may adversely affect the trading price of our common stock. Additionally, general economic, political and market conditions, such as recessions, interest rates or international currency fluctuations may adversely affect the market price of our common stock. Due to the limited volume of our shares which trade, we believe that our stock prices (bid, ask and closing prices) may not be related to our actual value, and not reflect the actual value of our common stock. You should exercise caution before making an investment in us.

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Additionally, as a result of the illiquidity of our common stock, investors may not be interested in owning our common stock because of the inability to acquire or sell a substantial block of our common stock at one time. Such illiquidity could have an adverse effect on the market price of our common stock. In addition, a stockholder may not be able to borrow funds using our common stock as collateral because lenders may be unwilling to accept the pledge of securities having such a limited market. An active trading market for our common stock may not develop or, if one develops, may not be sustained.

A prolonged decline in the market price of our common stock could affect our ability to obtain additional financing which would adversely affect our operations.

Historically, we have relied on equity and debt financing as primary sources of financing. A prolonged decline in the market price of our common stock or a reduction in our accessibility to the global markets may result in our inability to secure additional financing which would have an adverse effect on our operations.

The warrants sold in our April 2014 offering have anti-dilution rights which could cause their exercise price to be reduced.

The warrants sold in our April 2014 offering include anti-dilution rights, which provide that if at any time the warrants are outstanding (i.e., through April 2019), we issue or are deemed to have issued (which includes shares issuable upon exercise of warrants and options and conversion of convertible securities) for consideration less than the then current exercise price of the warrants, the exercise price of such warrants is automatically reduced (a) to the lowest price per share of consideration provided or deemed to have been provided for such securities, not to be deemed less than $0.01 per share, during the one year period following the closing date of the offering (April 21, 2014), which date passed without any required adjustments; and thereafter (b) to the product of (x) the exercise price then in effect, and (y) a fraction, the numerator of which is the number of shares of common stock outstanding immediately prior to such issuance plus the number of shares of common stock which the aggregate consideration received by us would purchase at the exercise price in effect immediately prior to such issuance, and the denominator of which is the number of shares of common stock outstanding immediately prior to such issuance plus the number of such additional shares of common stock issued. Notwithstanding the above, no adjustment of the exercise price is required in connection with any issuances or deemed issuance of shares of common stock (1) to our officers, directors, consultants or employees pursuant to stock option or stock purchase plans or agreements on terms approved by our Board of Directors, subject to adjustment for all subdivisions and combinations; and (2) in connection with the re-negotiation, modification, extension or re-pricing of debt of the Company outstanding on the closing date, subject to the prior written approval of the holders of the warrants. Additionally, in the event we acquire ownership of another entity or a significant amount of assets from another person or entity by way of an asset purchase agreement, merger (pursuant to which we are the surviving entity and our common stock is not converted or exchanged), business combination or share exchange pursuant to which shares of our common stock or convertible securities (including options or warrants) are issued or granted by us as partial or sole consideration to the counterparty or counterparties in such transaction or series of transactions (a “Company Combination”), then and in such event, the exercise price of the warrants is automatically reduced, to the average of the highest bid and lowest asked prices of our common stock averaged over the thirty (30) business days after the closing of the Company Combination if such exercise price as adjusted is less than the exercise price in effect on the date such Company Combination Price is determined.

Nevada law and our Articles of Incorporation authorize us to issue shares of stock which shares may cause substantial dilution to our existing stockholders.

We have authorized capital stock consisting of 500,000,000 shares of common stock, $0.001 par value per share and 10,000,000 shares of preferred stock, $0.001 par value per share. As of June 28, 2018, we had 15,574,255 shares of common stock outstanding, 408,508 shares of Series B Preferred Stock outstanding and 1,112 shares of Series C Preferred Stock outstanding (each as described in greater detail below under “Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities” - “Description of Capital Stock” - “Preferred Stock”). As a result, our Board of Directors has the ability to issue a large number of additional shares of common stock without stockholder approval, subject to the requirements of the NYSE American (which generally require stockholder approval for any transactions which would result in the issuance of more than 20% of our then outstanding shares of common stock or voting rights representing over 20% of our then outstanding shares of stock), which if issued could cause substantial dilution to our then stockholders. Shares of additional preferred stock may also be issued by our Board of Directors without stockholder approval, with voting powers and such preferences and relative, participating, optional or other special rights and powers as determined by our Board of Directors, which may be greater than the shares of common stock currently outstanding. As a result, shares of preferred stock may be issued by our Board of Directors which cause the holders to have majority voting power over our shares, provide the holders of the preferred stock the right to convert the shares of preferred stock they hold into shares of our common stock, which may cause substantial dilution to our then common stock stockholders and/or have other rights and preferences greater than those of our common stock stockholders. Investors should keep in mind that the Board of Directors has the authority to issue additional shares of common stock and preferred stock, which could cause substantial dilution to our existing stockholders. Additionally, the dilutive effect of any preferred stock which we may issue may be exacerbated given the fact that such preferred stock may have super voting rights and/or other rights or preferences which could provide the preferred stockholders with substantial voting control over us subsequent to the date of this prospectus and/or give those holders the power to prevent or cause a change in control. As a result, the issuance of shares of common stock and/or Preferred Stock may cause the value of our securities to decrease and/or become worthless.

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Stockholders may be diluted significantly through our efforts to obtain financing and/or satisfy obligations through the issuance of additional shares of our common stock.

Wherever possible, our Board of Directors will attempt to use non-cash consideration to satisfy obligations. In many instances, we believe that the non-cash consideration will consist of shares of our common stock. Subject to certain consent rights of the investor in our April 2016/October 2017 financings, our Board of Directors has authority, without action or vote of the stockholders, to issue all or part of the authorized but unissued shares of common stock (subject to NYSE American rules which limit among other things, the number of shares we can issue without stockholder approval to no more than 20% of our outstanding shares of common stock). These actions will result in dilution of the ownership interests of existing stockholders, and that dilution may be material.

If persons engage in short sales of our common stock, including sales of shares to be issued upon exercise of our outstanding warrants, convertible debentures and preferred stock, the price of our common stock may decline.

Selling short is a technique used by a stockholder to take advantage of an anticipated decline in the price of a security. In addition, holders of options, warrants and other convertible securities will sometimes sell short knowing they can, in effect, cover through the exercise or conversion of options, warrants and other convertible securities, thus locking in a profit. A significant number of short sales or a large volume of other sales within a relatively short period of time can create downward pressure on the market price of a security. Further sales of common stock issued upon exercise or conversion of options, warrants and other convertible securities could cause even greater declines in the price of our common stock due to the number of additional shares available in the market upon such exercise/conversion, which could encourage short sales that could further undermine the value of our common stock. You could, therefore, experience a decline in the value of your investment as a result of short sales of our common stock.

The market price for our common stock may be volatile, and our stockholders may not be able to sell our stock at a favorable price or at all.

Many factors could cause the market price of our common stock to rise and fall, including: actual or anticipated variations in our quarterly results of operations; changes in market valuations of companies in our industry; changes in expectations of future financial performance; fluctuations in stock market prices and volumes; issuances of dilutive common stock or other securities in the future; the addition or departure of key personnel; announcements by us or our competitors of acquisitions, investments or strategic alliances; and the increase or decline in the price of oil and natural gas.

Substantial sales of our common stock, or the perception that such sales might occur, could depress the market price of our common stock.

We cannot predict whether future issuances of our common stock or resales in the open market will decrease the market price of our common stock. The impact of any such issuances or resales of our common stock on our market price may be increased as a result of the fact that our common stock is thinly, or infrequently, traded. The exercise of any options that we have or that we may grant to directors, executive officers and other employees in the future, the issuance of common stock in connection with acquisitions and other issuances of our common stock (including shares previously registered in our registration statements and prospectus supplements, and/or in connection with future registration statements or prospectus supplements) could have an adverse effect on the market price of our common stock. In addition, future issuances of our common stock may be dilutive to existing stockholders. Any sales of substantial amounts of our common stock in the public market, or the perception that such sales might occur, could lower the market price of our common stock.

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We incur significant costs as a result of operating as a fully reporting publicly traded company and our management is required to devote substantial time to compliance initiatives.

We incur significant legal, accounting and other expenses in connection with our status as a fully reporting public company. Specifically, we are required to prepare and file annual, quarterly and current reports, proxy statements and other information with the SEC. Additionally, our officers, directors and significant stockholders are required to file Forms 3, 4 and 5 and Schedules 13D/G with the SEC disclosing their ownership of the Company and changes in such ownership. Furthermore, the Sarbanes-Oxley Act of 2002 (the “Sarbanes-Oxley Act”) and rules subsequently implemented by the SEC have imposed various new requirements on public companies, including requiring changes in corporate governance practices. In addition, the Sarbanes-Oxley Act requires, among other things, that we maintain effective internal controls for financial reporting and disclosure of controls and procedures. The costs and expenses of compliance with SEC rules and our filing obligations with the SEC, or our identification of deficiencies in our internal controls over financial reporting that are deemed to be material weaknesses, could materially adversely affect our results of operations or cause the market price of our stock to decline in value.

Securities analyst coverage or lack of coverage may have a negative impact on our common stock’s market price.

The trading market for our common stock will depend, in part, on the research and reports that securities or industry analysts publish about us or our business. We do not have any control over these analysts. If securities or industry analysts stop their coverage of us or additional securities and industry analysts fail to cover us in the future, the trading price for our common stock would be negatively impacted. If any analyst or analysts who cover us downgrade our common stock, changes their opinion of our shares or publishes inaccurate or unfavorable research about our business, our stock price would likely decline. If any analyst or analysts cease coverage of us or fail to publish reports on us regularly, demand for our common stock could decrease and we could lose visibility in the financial markets, which could cause our stock price and trading volume to decline.

Due to the fact that our common stock is listed on the NYSE American, we are subject to financial and other reporting and corporate governance requirements which increase our cost and expenses.

We are currently required to file annual and quarterly information and other reports with the SEC that are specified in Sections 13 and 15(d) of the Exchange Act. Additionally, due to the fact that our common stock is listed on the NYSE American, we are also subject to the requirements to maintain independent directors, comply with other corporate governance requirements and are required to pay annual listing and stock issuance fees. These obligations require a commitment of additional resources including, but not limited, to additional expenses, and may result in the diversion of our senior management’s time and attention from our day-to-day operations. These obligations increase our expenses and may make it more complicated or time consuming for us to undertake certain corporate actions due to the fact that we may require the approval of the NYSE American for such transactions and/or NYSE American rules may require us to obtain stockholder approval for such transactions.

You may experience future dilution as a result of future equity offerings or other equity issuances.

We may in the future issue additional shares of our common stock or other securities convertible into or exchangeable for our common stock.

Risks Relating to the LOI

 

On June 25, 2018, the Company entered into a non-binding letter of intent with an entity affiliated with Mr. Azar and Donnie B. Seay, our current director (the “LOI”). The LOI contemplates the Company and the entity entering into, among other agreements, an asset purchase agreement whereby the Company will transfer substantially all of its assets to the entity, reserving its assets in Glasscock County and Hutchinson Counties, Texas and will also retain a 12.5% production payment and a 3% overriding royalty interest in its existing Okfuskee County, Oklahoma asset, in consideration for the entity assuming all of the Company’s senior bank debt owed to IBC. The LOI is subject to various conditions, as are the transactions contemplated therein, including, but not limited to, approval of IBC and approval of the Company’s shareholders for the contemplated transactions.

 

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Failure to complete the transactions contemplated by the LOI could negatively impact our stock price and future business and financial results.

 

If the transactions contemplated by the LOI (the “LOI Transactions”) are not completed, our ongoing business may be adversely affected and we would be subject to a number of risks, including the following:

 

  we will not realize the benefits expected from the LOI Transactions, including a significant reduction in outstanding debt and will remain in default of the IBC Bank loan agreement;
  we may experience negative reactions from the financial markets and our partners and employees;
  IBC Bank may foreclose on our assets securing the IBC debt; and
  matters relating to the LOI Transactions may require substantial commitments of time and resources by our management, which would otherwise have been devoted to other opportunities that may have been beneficial to us as an independent company.

 

We will be subject to business uncertainties and contractual restrictions while the LOI Transactions are pending.

 

Uncertainty about the effect of the LOI Transactions on employees and partners may have an adverse effect on us. These uncertainties may impair our ability to attract, retain and motivate key personnel until the LOI Transactions are completed or terminated, and could cause partners and others that deal with us to seek to change existing business relationships, cease doing business with us or cause potential new partners to delay doing business with us until the LOI Transactions have been successfully completed. Retention of certain employees may be challenging during the pendency of the LOI Transactions, as certain employees may experience uncertainty about their future roles or compensation structure. If key employees depart because of issues relating to the uncertainty and difficulty of integration or a desire not to remain with the business, our business following the LOI Transactions could be negatively impacted. In addition, the LOI Transactions restrict us from taking other specified actions until the LOI Transactions are completed. These restrictions may prevent us from pursuing attractive business opportunities that may arise prior to the completion of the LOI Transactions.

 

Completion of the LOI Transactions are subject to a number of conditions and if these conditions are not satisfied or waived, the LOI Transactions will not be completed.

 

The LOI Transactions are subject to customary closing conditions, including (1) approval by our stockholders in connection with the LOI Transactions and (2) approval of the transactions by IBC Bank. Failure to fulfill any of such closing conditions could prevent us from completing the LOI Transactions and have a material adverse effect on the Company.

 

Termination of the LOI or LOI Transactions could negatively impact us.

 

In the event the LOI or LOI Transactions are terminated, our business may be adversely impacted by our failure to pursue other beneficial opportunities due to the focus of management on the LOI Transactions, and the market price of our common stock might decline to the extent that the current market price reflects a market assumption that the LOI Transactions will be completed.

 

If the benefits of the LOI Transactions do not meet the expectations of the marketplace, or financial or industry analysts, the market price of our common stock may decline.

 

The market price of our common stock may decline as a result of the LOI Transactions if we do not otherwise achieve the perceived benefits of the LOI Transactions as rapidly as, or to the extent, anticipated by the marketplace, or financial or industry analysts. Accordingly, investors may experience a loss as a result of a decreasing stock price and we may not be able to raise future capital, if necessary, in the equity markets.

 

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In the event the LOI Transactions close, we may purse acquisition and/or merger opportunities and/or affect a change in business focus.

 

In the event the LOI Transactions close, we may purse acquisition and/or merger opportunities to enhance our value and growth prospects, which may result in a change in business focus. As a result our majority shareholders may change and new shares of common or preferred stock may be issued, resulting in substantial dilution to our then current shareholders. As a result, if there were new majority shareholders, they may change the composition of our Board of Directors and replace our current management. The new management may change, and/or acquisition or merger opportunities may result in the change of, our business focus and we can make no assurances that our future management will be able to properly manage the Company or that any change in our business focus will be successful. If we do not affect an acquisition and/or enter into merger or business combinations subsequent to affecting the LOI Transactions, we may be forced to scale back or abandon our operations, which may cause the value of our common stock to decline or become worthless.

 

Risks Related To Our Outstanding Convertible Securities

Due to the occurrence of a trigger event under, and other adjustment mechanisms related to, the First Warrant, the premium associated therewith increased to 17% per annum and upon the exercise thereof, the premium through maturity was due in full.

 

A trigger event under the First Warrant occurred on June 30, 2016. As a result thereof, and as a result of certain other adjustment mechanisms in the First Warrant, the premium on the First Warrant increased from 6% per annum to 17% per annum. Pursuant to the terms of the First Warrant, the premium through maturity (i.e., seven years) was due upon exercise of the First Warrant. The premium is payable by way of the conversion of the total premium payable in connection therewith $5,355,000 into shares of our common stock at a discount to the volume weighted average sales price of our common stock during a specified measurement period. As such, as long as the value of our common stock continues to decline in value, the Investor may be due more shares of common stock, which issuances will significantly dilute existing shareholders and the sale of which securities will likely result in the continuous decline in the value of our common stock, thereby resulting in even more shares being due to the Investor. As of June 28, 2018, a total of 4.9 million shares of common stock had been issued to the Investor in connection with the exercise of the First Warrant.

 

The full amount of premiums, interest and dividends through the maturity date of each applicable security is due upon the repayment/redemption (where applicable), exercise or conversion, as applicable, of the Debenture and Series C Preferred Stock.

 

The Debenture and Series C Preferred Stock provide that all applicable interest (due under the terms of the Debenture), and dividends (due under the terms of the Series C Preferred Stock), which each initially accrued in the amount of 6% per annum and which increase or decrease subject to the terms of the applicable securities, based on among other things, the trading price of the Company’s common stock, up to a maximum of 34.95% per annum (which pursuant to the Investor, are the current applicable percentage interest rates for the Debenture and the shares of Series C Preferred Stock sold in April 2016, with the applicable percentage rate of the Series C Preferred Stock sold in October 2017, having an applicable percentage rate of 24.95%), are due upon exercise or conversion, or repayment/redemption (where applicable) thereof, for the full seven year term of such securities.

 

The requirement that we pay all premiums, interest and dividends through maturity and the adjustable nature of such premium, interest and dividend rates, may force us to issue the Investor significant additional shares of common stock (similar to the currently disclosed required issuance to the Investor under the First Warrant), which may cause significant dilution to existing stockholders. The requirement that we pay all premiums, interest and dividends through maturity may make it too costly for us to repay or redeem, as applicable, the Investor’s securities, prior to exercise/conversion thereof, as applicable.

 

The number of shares of common stock issuable in consideration for premiums, interest and dividends through maturity on the First Warrant, Debenture and Series C Preferred Stock, continue to be adjustable after the exercise or conversion of such securities.

 

Pursuant to the terms of the First Warrant, Debenture and Series C Preferred Stock, the conversion rate of such securities in connection with the premiums, interest and dividends due on such securities through maturity (each 7 years, regardless of when converted or exercised), continues to be adjustable after the issuance of such securities. Specifically, such securities remain adjustable, based on a discount to the lowest daily volume weighted average price during a measuring period for a period of 60 days after the applicable number of shares stated in the initial exercise/conversion notice have actually been received into the Investor’s designated brokerage account in electronic form and fully cleared for trading (subject to certain extensions described in the applicable securities). Because the Investor is limited to holding not more than 4.99% of the Company’s common stock upon exercise/conversion of any security, the Investor will not receive all of the shares due upon any exercise/conversion, until it has sold shares and been issued additional shares and as such, the beginning date for the applicable 30 or 60 day period after issuance/conversion is impossible to determine and may be a significant additional number of days after the initial exercise/conversion by the Investor.

 

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In the event of a decrease in the Company’s stock price during the applicable measuring periods, the conversion rate of the premiums, interest and dividends due on such applicable securities will adjust downward and the Investor will be due additional shares of common stock, which issuances may cause further significant dilution to existing shareholders and the sale of such shares may cause the value of the Company’s common stock to decline in value. Furthermore, it is likely that the sale by the Investor of the shares of common stock which the Investor receives in connection with any exercise/conversion, including, but not limited to the shares of common stock which the Investor received in connection with the exercise of the First Warrant, during the applicable measuring period, will cause the value of the Company’s common stock to decline in value and the conversion rate to decrease and will result in the Investor being due additional shares of common stock during the measuring period, which will trigger additional decreases in the value of the Company’s common stock upon further public sales by the Investor. If this were to occur, the Investor would be entitled to receive an increasing number of shares, upon exercise/conversion of the remaining securities, which could then be sold, triggering further price declines and exercises/conversions for even larger numbers of shares, which would cause additional dilution to our existing stockholders and would likely cause the value of our common stock to decline.

 

The issuance of common stock upon conversion of the Debenture and Series C Preferred Stock will cause immediate and substantial dilution and the sale of such stock will cause significant downward pressure on our stock price.

 

The issuance of common stock upon conversion of the Debenture and Series C Preferred Stock will result in immediate and substantial dilution to the interests of other stockholders. Although the Investor may not receive shares of common stock exceeding 4.99% of our outstanding shares of common stock immediately after affecting such exercise/conversion, this restriction does not prevent the Investor from receiving shares up to the 4.99% limit, selling those shares, and then receiving the rest of the shares it is due, in one of more tranches, while still staying below the 4.99% limit. If the Investor chooses to do this, it will cause substantial dilution to the then holders of our common stock. Additionally, the continued sale of shares issuable upon successive conversions/exercises will likely create significant downward pressure on the price of our common stock as the Investor sells material amounts of our common stock over time and/or in a short period of time. This could place further downward pressure on the price of our common stock and in turn result in the Investor receiving an ever increasing number of additional shares of common stock upon exercise/conversion of its securities, and adjustments thereof, which in turn will likely lead to further dilution, reductions in the exercise/conversion price of the Investor’s securities and even more downward pressure on our common stock, which could lead to our common stock becoming devalued or worthless.

 

The Investor, subject to applicable contractual restrictions, and/or a third party, may sell short our common stock, which could have a depressive effect on the price of our common stock.

 

As described above, the conversion price for the value of premiums, interest and dividends due in connection with the First Warrant, Debenture and Series C Preferred Stock, is based on a discount to the trading price of the Company’s common stock. The Investor is not currently prohibited from selling the Company’s stock short. Additionally, nothing prohibits a third party from selling the Company’s common stock short based on their belief that due to the dilution caused by the conversions/exercises of the securities held by the Investor, that the trading price of the Company’s common stock will decline in value. The significant downward pressure on the price of our common stock as the Investor sells material amounts of our common stock could encourage investors to short sell our common stock. This could place further downward pressure on the price of our common stock and in turn result in the Investor receiving additional shares of common stock upon exercise/conversion of its securities, and adjustments thereof.

 

 

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The Company is limited in its ability to undertake subsequent financings.

 

Until the later of (a) six months after the entire Debenture has been converted or redeemed; and (b) the date that the Investor no longer holds any shares of Series C Preferred Stock, we agreed that we would not issue or enter into or amend an agreement pursuant to which we may issue any shares of common stock, other than (a) for restricted securities with no registration rights, (b) in connection with a strategic acquisition, (c) in an underwritten public offering, or (d) at a fixed price; or issue or amend any debt or equity securities convertible into, exchangeable or exercisable for, or including the right to receive, shares of common stock (i) at a conversion price, exercise price or exchange rate or other price that is based upon or varies with, the trading prices of or quotations for the shares of common stock at any time after the initial issuance of the security or (ii) with a conversion, exercise or exchange price that is subject to being reset at some future date after the initial issuance of the security or upon the occurrence of specified or contingent events directly or indirectly related to the business of the Company or the market for the common stock. These restrictions may make it more costly for us to raise funding in the future or may limit our ability to raise funding, which could force us to curtail our business plan or prohibit us from taking advantage of attractive investment, acquisition or drilling activities. All of which could have a negative effect on the value of our common stock and our near-term or long-term prospects.

 

ITEM 2. PROPERTIES.

Areas of Activities

We operate and invest in areas that are known to be productive, with a reasonably established production history, in order to decrease geological and exploratory risk. In 2016, the Company acquired over 13,000 net acres in producing fields located primarily in the Mid-Continent region of Oklahoma including Payne, Lincoln and Logan Counties, along with a small amount of interest in production located in Glasscock County, Texas. The Mid-Continent assets produce from a liquids-rich, gas reservoir known as the Hunton formation. These properties include interests in four different fields, of which one is operated by Camber and the other three are non-operated. In January 2018, the Company acquired 3,000 net acres in Okfuskee, Oklahoma. Our Glasscock County, Texas properties produce oil and gas primarily from the Wolfberry, Cline and Fusselman formations and are all non-operated. In March 2018, the Company acquired 500 net acres, 49 non-producing well bores and five saltwater disposal wells in Hutchinson County, Texas. In November of 2017, the Company sold approximately 2,600 net acres in the Permian Basin in Gaines County, Texas. The Company intends to sell or farm out its remaining acres in this area.

 

The following table summarizes our gross and net developed and undeveloped leasehold and mineral fee acreage at March 31, 2018. Acreage in which our interest is limited to royalty and overriding royalty interests is excluded:

 

Acreage

 

   Total  Developed  Undeveloped
   Gross  Net  Gross  Net  Gross  Net
Central Oklahoma / Midcontinent   57,947    19,126    48,318    16,075    9,629    3,051 
West Texas   20,768    859    4,445    859    16,323     
Total   78,715    19,985    52,763    16,934    25,952    3,051 

 

(1) Developed acreage is the number of acres that are allocated or assignable to producing wells or wells capable of production.

 

(2) Undeveloped acreage is lease acreage on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of oil and natural gas regardless of whether such acreage includes proved reserves.

 

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We believe we have satisfactory title, in all material respects, to substantially all of our producing properties in accordance with standards generally accepted in the oil and natural gas industry. Substantially all of our proved oil and natural gas properties are pledged as collateral for outstanding loans.

 

Total Net Undeveloped Acreage Expiration

 

In the event that production is not established or we take no action to extend or renew the terms of our leases, our 423 undeveloped acres will expire within the next year.

 

Production, Sales Price and Production Costs

 

The Company produced oil, natural gas and NGLs from 92 wells in four Texas counties and three Oklahoma counties in the Mid-Continent regions during the year ended March 31, 2018. The number of operated gross wells was 87 wells and the total number of gross wells was 174, with the active producers being 86, as of the date of this report.

 

The following tables represent our total production, average sales prices and average production costs for the years ended March 31, 2018 and 2017:

 

   2018  2017
 Net Operating Revenues:          
Crude Oil  $1,198,514   $1,654,589 
Natural Gas   2,051,846    1,636,212 
NGL   3,609,407    2,011,223 
Total Revenues  $6,859,767   $5,302,024 
           
Production sales:          
Crude oil (Bbls)   27,704    36,331 
Natural gas (Mcf)   796,384    546,644 
NGL (Gallons)   6,177,153    4,095,651 
Total (barrels oil equivalent or Boe) (1)   307,510    224,954 
           
Average Sales Price:          
Crude Oil ($/Bbl)  $43.26   $45.54 
Natural Gas ($/Mcf)   2.58    2.99 
NGL ($/Gal)   0.58    0.49 
           
Average Production Cost ($/Boe):  $16.83   $15.64 

 

As of March 31, 2018, production from the Pilgrim and Twin Cities fields are the only field that comprises 15% or more of our total proved reserves as of that date. The production volumes for the years ended March 31, 2018 and 2017 are represented in the table below:

 

   2018  2017
Pilgrim          
Crude oil (Bbls)   8,531    1,368 
Natural gas (Mcf)       53,360 
NGL (Bbls)       57,944 
           
Twin Cities          
Crude oil (Bbls)   8,448    2,397 
Natural gas (Boe)   79,786    27,267 
NGL (Bbls)   85,138    31,324 

 

 

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Well Summary

 

The following table presents our ownership in productive crude oil and natural gas wells at March 31, 2018. This summary includes wells in which we have a working interest:

 

Gross   Net  
Texas:   28   1 
Oklahoma:   58   31 
 Total   86   32 

 

Drilling Activity

 

In the years ended March 31, 2018 and 2017, the Company participated in the drilling of 0 and 2 net wells, respectively (as shown below).

 

Additionally as of March 31, 2018 and 2017, respectively, we had no delivery commitments.

 

  Net Wells Drilled
  2018  2017
  Gross  Net  Gross  Net
Development            
 Productive    —      —      2      2   
 Day    —      —      —      —   
Exploratory                     
 Productive    —      —      —      —   
 Day    —      —      —      —   

  

At March 31, 2018, we had no gross or net wells that were in the process of being drilled nor did we have any delivery commitments.

 

 

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Oil and Natural Gas Reserves

 

Reserve Information. For estimates of Camber’s net proved producing reserves of crude oil and natural gas, as well as discussion of Camber’s proved and probable undeveloped reserves, see “Item 8 Financial Statements and Supplementary Data” – “Supplemental Oil and Gas Disclosures (Unaudited)”. At March 31, 2018, Camber’s total estimated proved reserves were 2.9 million Boe of which 0.1 million Bbls were crude oil reserves, 1.4 million Bbls were NGL reserves and 8.1 million Mcfs were natural gas reserves.

 

Internal Controls. Jim Williams, is the technical person primarily responsible for our internal reserves estimation process (which are based upon the best available production, engineering and geologic data) and provides oversight of the annual audit of our year end reserves by our independent third party engineers. Mr. Williams serves as a consultant through the Company’s contract operator Petroglobe. Mr. Williams has over 35 years’ experience in upstream oil and gas and has worked in the states of Oklahoma, Texas, Kansas, New Mexico, Colorado, Arkansas, Louisiana, North Dakota, Montana, Utah, Wyoming and Alaska. Mr. Williams graduated from the University of North Dakota with a bachelor’s degree in Chemical Engineering and started his career with Shell Offshore in New Orleans, Louisiana as a Petrophysical Logging and Drilling Engineer. In 1984, he joined DRD Corporation in Tulsa, Oklahoma and was Product Manager, WELLPLAN drilling and directional planning software. He traveled to over 40 countries and gained extensive experience in directional and horizontal drilling operations while implementing WELLPLAN in major, independent and national oil and gas companies. During his tenure, DRD was eventually sold to Landmark Graphics, a subsidiary of Halliburton. Mr. Williams then moved into the role of Product Manager for the Gas Research Institute’s Successful Drilling Practices (SDP) managed by Oil and Gas Consultants Intl. Following SDP, he moved into drilling contractor, E&P operational and reservoir engineering roles with several notable companies in Tulsa, Oklahoma including Parker Drilling, Latigo Petroleum, Cimarex Energy, IHSMarkit and Kaiser-Francis Oil Company. In 2014, Mr. Williams joined GroundMetrics, a San Diego startup, and opened their Tulsa, Oklahoma office for the purpose of offering 3D, full-field resistivity mapping to operators in Oklahoma, Kansas and Texas. After GroundMetrics, he worked at Equal Energy as Reservoir Engineer and managed the corporate reserves database for all operated and non-operated properties. Mr. Williams’ experience includes development of Edwards Lime, Frio, Vicksburg, Wilcox, Weiting and Yegua Cook Mountain reservoirs along the Texas Gulf Coast; Brown Dolomite, Cleveland, Hogshooter, Granite Wash, Morrow and Atoka shale reservoirs in western Oklahoma and the Texas Panhandle; Bartlesville, Skinner, Prue, Hunton, Mississippi Lime and Arbuckle reservoirs in central and northern Oklahoma; and the Almond and Dakota reservoirs in the Green River Basin West. Mr. Williams is a member of the Society of Petroleum Engineers, the American Association of Petroleum Geologists, the Society of Petrophysicists and Well Log Analysts and the Professional Petroleum Data Management Association.

 

The preparation of our reserve estimates is in accordance with our prescribed procedures that include verification of input data into a reserve forecasting and economic software, as well as management review. Our reserve analysis includes but is not limited to the following:

 

Research of operators near our lease acreage. Review operating and technological techniques, as well as reserve projections of such wells.
The review of internal reserve estimates by well and by area by a qualified petroleum engineer. A variance by well to the previous year-end reserve report is used as a tool in this process.
SEC-compliant internal policies to determine and report proved reserves.
The discussion of any material reserve variances among management to ensure the best estimate of remaining reserves.

 

Qualifications of Third Party Engineers. For the year ended March 31, 2018, the technical person responsible for the audit of our reserve estimates at Graves & Co. Consulting LLC was Allen C. Barron, who meets the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. For the year ended March 31, 2017, the technical person primarily responsible for the audit of our reserves estimates at Ralph E. Davis Associates, LLC was Curt Taylor, who meets the requirements regarding qualifications, independence, objectivity, and confidentiality set forth in the Standards Pertaining to the Estimating and Auditing of Oil and Gas Reserves Information promulgated by the Society of Petroleum Engineers. Both Graves & CO. Consulting LLC and Ralph E. Davis Associates, LLC are independent firms and do not own an interest in our properties and are not employed on a contingent fee basis. Reserve estimates are imprecise and subjective, and may change at any time as additional information becomes available. Furthermore, estimates of oil and gas reserves are projections based on engineering data. There are uncertainties inherent in the interpretation of this data as well as the projection of future rates of production. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. A copy of the report issued by Graves & Co. Consulting LLC is filed with this report as Exhibit 99.1.

For more information regarding our oil and gas reserves, please refer to “Item 8 Financial Statements and Supplementary Data” – “Supplemental Oil and Gas Disclosures (Unaudited)”.

 

Office Lease

 

On April 1, 2016, the Company entered into a lease agreement pursuant to which the Company agreed to lease 4,439 square feet of office space at 450 Gears Road, Houston, Harris County, Texas 77067 (Suite 860, versus Suite 780 as was leased previously). The lease had a 65-month term (through August 2021), and commenced on April 1, 2016. The monthly rental cost under the lease was $-0- for the month of April 2016, and $7,676 for the months of May 2016 through April 2017, plus as applicable, its pro rata share of operating expenses and taxes which exceed the total operating expenses and taxes of the property for the first year of the lease. On March 31, 2017, the Company amended its lease at 450 Gears Road to expand to a total of 6,839 square feet, commencing on May 1, 2017. The amendment extended the lease period to November 2021.

 

 

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In August 2017, the Company ceased its use of this office space and moved its headquarters to San Antonio, Texas. The Company is committed to the remaining lease payments for the Houston office space for approximately $346,000 assuming an early termination of the lease on July 31, 2019. The Company recorded monthly rent expense associated with the Houston lease through August 2017. In accordance with the accounting guidance in ASC 420-10-25-13 regarding exit or disposal cost obligations, as of August 2017, the Company recorded rent expense, within general and administrative expense, and accrued a liability of $302,289, which represents the fair value of costs that will continue to be incurred during the remaining term of the Houston lease without economic benefit to the Company. As of March 31, 2018, the remaining carrying amount of the liability of $226,972 was included in accrued expenses on the Company’s balance sheet. In addition, the Company wrote-off $189,533 of mostly fully depreciated property and equipment that was not re-located to the San Antonio headquarters resulting in a loss of $3,368.

 

Effective October 1, 2017, the Company entered into an agreement to sublease space on a month to month basis in San Antonio, Texas at 4040 Broadway, Suite 425 from RAD2 Minerals, Ltd., an entity owned and controlled by Mr. Azar, the Company’s former Interim Chief Executive Officer, who resigned as Interim CEO effective May 25, 2018 and resigned as a member of the Board of Directors on June 21, 2018. Monthly rent for October through December 2017 was $5,000 per month increasing to $7,500 per month effective January 2018 . The lease agreement was terminated effective June 30, 2018. The Company agreed under a verbal contract to lease the same space on a month to month basis for $2,500 per month beginning effective July 1, 2018.

 

ITEM 3. LEGAL PROCEEDINGS

 

From time to time, the Company may become party to litigation or other legal proceedings that it considers to be a part of the ordinary course of its business. The Company is not currently involved in any legal proceedings that it believes could reasonably be expected to have a material adverse effect on our business, prospects, financial condition or results of operations. The Company may become involved in material legal proceedings in the future. Below is a summary of certain legal proceedings involving the Company which the Company believes will not have a material adverse effect on its business, prospects, financial condition or results of operations.

 

Maranatha Oil Matter

 

In November 2015, Randy L. Robinson, d/b/a Maranatha Oil Co. sued the Company in Gonzales County, Texas (Cause No. 26160). The plaintiff alleged that it assigned oil and gas leases to the Company in April 2010, retaining a 4% overriding royalty interest and 50% working interest and that the Company failed to pay such overriding royalty interest or royalty interest. The interests relate to certain oil and gas properties which the Company subsequently sold to Nordic Oil USA in April 2013. The petition alleges causes of actions for breach of contract, failure to pay royalties, non-payment of working interest, fraud, fraud in the inducement of contract, money had and received, constructive trust, violation of theft liability act, continuing tort and fraudulent concealment. The suit seeks approximately $100,000 in amounts alleged owed, plus pre-and post-judgment interest. We have filed a denial to the claims.

 

Rubenstein Matter

 

On September 28, 2017, Aaron Rubenstein, a purported shareholder of the Company’s common stock, filed a lawsuit against the Company (as nominal defendant) and Richard N. Azar II, the Company’s then Chief Executive Officer and director (who has since resigned from both positions), RAD2 Management, LLC, RAD2 Minerals, Ltd. and Segundo Resources, LLC, each an entity owned and controlled by Mr. Azar, in the United States District Court, Western District of Texas (Case No. 5:17-cv-962-FB).  The suit seeks the recovery (for the benefit of the Company) of alleged short-swing profits from Mr. Azar and his related entities under Section 16(b) of the Exchange Act relating to various transactions involving Series B Preferred Stock of the Company in November 2016 and January 2017. Mr. Azar denies the existence of any short-swing profits and filed a denial with the court. The Company also filed a denial with the court.

 

Petroflow Matter

 

In October 2017, the Company agreed to pay directly and reimburse entities owned in part by Alan Dreeben, a former director of the Company, for legal fees and settlement payments expended in connection with the defense of Petroflow Energy Corporation v. Sezar Energy, L.P. and Brittany Energy, LLC, Case No. 16-CV-700-TCK;TLW, In the United States District Court – N.D. OK. The Company was the beneficiary through the release of interest in disputed lease interests from Petroflow Energy Corporation (“Petroflow”) to the Company that provides the Company with complete control over those properties to renew expired leases and to have 100% of the drilling rights related to those properties. Sezar Energy, L.P. (“Sezar Energy”) and Brittany Energy, LLC (“Brittany Energy”) have assigned any interests they may have had in conjunction with litigation in exchange for the Company making the agreed settlement payments of $475,000 plus direct payments and reimbursement of the legal costs paid on behalf of the defendants by Mr. Dreeben. Total legal fees expended by such entities totaled $392,043, and the Company reimbursed such fees by issuing Mr. Dreeben 78,409 shares of common stock with a value of $5.00 per share in November 2017. In addition, the Company directly paid legal fees and settlement payments totaling $567,633. The total expense related to the Petroflow matter of $959,676 is included in General and Administrative expense on the income statement.

 

 

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ITEM 4.  MINE SAFETY DISCLOSURES

 

Not applicable.

 

 

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PART II

 

ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES.

 

Market Information

 

Our common stock is quoted on the NYSE American under the symbol CEI. Set forth in the table below are the quarterly high and low sales prices of our common stock on the NYSE American for the past two fiscal years. Prices represent inter-dealer quotations without adjustments for markups, markdowns, and commissions, and may not represent actual transactions. The below table takes into account our 1:25 reverse stock split which took place on March 5, 2018.

 

  High  Low
2018    
 Quarter ended March 31, 2018   $3.88   $0.71 
 Quarter ended December 31, 2017    10.00    2.60 
 Quarter ended September 30, 2017    11.25    4.00 
 Quarter ended June 30, 2017    15.50    4.00 
 2017          
 Quarter ended March 31, 2017   $36.25   $7.85 
 Quarter ended December 31, 2016    82.25    21.00 
 Quarter ended September 30, 2016    126.75    73.50 
 Quarter ended June 30, 2016    199.50    69.50 

 

 

Holders

 

As of June 28, 2018, there were approximately 155 record holders of our common stock, not including holders who hold their shares in street name.

 

Description of Capital Stock

 

The total number of shares of all classes of stock that we have authority to issue is 510,000,000, consisting of 500,000,000 shares of common stock, par value $0.001 per share, and 10,000,000 shares of preferred stock, par value $0.001 per share. As of June 28, 2018, we had (i) 15,574,255 shares of common stock outstanding, (ii) 2,000 designated shares of Series A Convertible Preferred Stock, none of which were outstanding, (iii) 600,000 designated shares of Series B Redeemable Convertible Preferred Stock, 408,508 of which were outstanding, and (iv) 5,000 designated shares of Series C Preferred Stock, 1,112 of which were outstanding.

Common Stock

Holders of our common stock: (i) are entitled to share ratably in all of our assets available for distribution upon liquidation, dissolution or winding up of our affairs; (ii) do not have preemptive, subscription or conversion rights, nor are there any redemption or sinking fund provisions applicable thereto; and (iii) are entitled to one vote per share on all matters on which stockholders may vote at all stockholder meetings. Each stockholder is entitled to receive the dividends as may be declared by our directors out of funds legally available for dividends. Our directors are not obligated to declare a dividend. Any future dividends will be subject to the discretion of our directors and will depend upon, among other things, future earnings, the operating and financial condition of our Company, our capital requirements, general business conditions and other pertinent factors.

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The presence of the persons entitled to vote 33% of the outstanding voting shares on a matter before the stockholders shall constitute the quorum necessary for the consideration of the matter at a stockholders’ meeting.

The vote of the holders of a majority of the votes cast on the matter at a meeting at which a quorum is present shall constitute an act of the stockholders, except for the election of directors, who shall be appointed by a plurality of the shares entitled to vote at a meeting at which a quorum is present. The common stock does not have cumulative voting rights, which means that the holders of a majority of the common stock voting for election of directors can elect 100% of our directors if they choose to do so.

Preferred Stock

Subject to the terms contained in any designation of a series of preferred stock, the Board of Directors is expressly authorized, at any time and from time to time, to fix, by resolution or resolutions, the following provisions for shares of any class or classes of preferred stock:

1)   The designation of such class or series, the number of shares to constitute such class or series which may be increased (but not below the number of shares of that class or series then outstanding) by a resolution of the Board of Directors;

 

2)   Whether the shares of such class or series shall have voting rights, in addition to any voting rights provided by law, and if so, the terms of such voting rights;

 

3)   The dividends, if any, payable on such class or series, whether any such dividends shall be cumulative, and, if so, from what dates, the conditions and dates upon which such dividends shall be payable, and the preference or relation which such dividends shall bear to the dividends payable on any share of stock of any other class or any other shares of the same class;

 

4)   Whether the shares of such class or series shall be subject to redemption by the Company, and, if so, the times, prices and other conditions of such redemption or a formula to determine the times, prices and such other conditions;

 

 5)   The amount or amounts payable upon shares of such series upon, and the rights of the holders of such class or series in, the voluntary or involuntary liquidation, dissolution or winding up, or upon any distribution of the assets, of the Company;

 

6)   Whether the shares of such class or series shall be subject to the operation of a retirement or sinking fund, and, if so, the extent to and manner in which any such retirement or sinking fund shall be applied to the purchase or redemption of the shares of such class or series for retirement or other corporate purposes and the terms and provisions relative to the operation thereof;

 

7)   Whether the shares of such class or series shall be convertible into, or exchangeable for, shares of stock of any other class or any other series of the same class or any other securities and, if so, the price or prices or the rate or rates of conversion or exchange and the method, if any, of adjusting the same, and any other terms and conditions of conversion or exchanges;

 

8)   The limitations and restrictions, if any, to be effective while any shares of such class or series are outstanding upon the payment of dividends or the making of other distributions on, and upon the purchase, redemption or other acquisition by the Company of the common stock or shares of stock of any other class or any other series of the same class;

 

9)   The conditions or restrictions, if any, upon the creation of indebtedness of the Company or upon the issuance of any additional stock, including additional shares of such class or series or of any other series of the same class or of any other class;

 

10)   The ranking (be it pari passu, junior or senior) of each class or series vis-à-vis any other class or series of any class of preferred stock as to the payment of dividends, the distribution of assets and all other matters;

 

11)   Facts or events to be ascertained outside the articles of incorporation of the Company, or the resolution establishing the class or series of stock, upon which any rate, condition or time for payment of distributions on any class or series of stock is dependent and the manner by which the fact or event operates upon the rate, condition or time of payment; and

 

 

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12)   Any other powers, preferences and relative, participating, optional and other special rights, and any qualifications, limitations and restrictions thereof, insofar as they are not inconsistent with the provisions of our articles of incorporation, as amended, to the full extent permitted by the laws of the State of Nevada.

 

The powers, preferences and relative, participating, optional and other special rights of each class or series of preferred stock, and the qualifications, limitations or restrictions thereof, if any, may differ from those of any and all other series at any time outstanding.

Series A Convertible Preferred Stock

The Series A Preferred Stock has no voting rights, no liquidation rights and no redemption rights, but has conversion rights providing the holder thereof the right to convert each outstanding share of Series A Preferred Stock into 40 shares of common stock. The Series A Preferred Stock contains a provision that limits the shares of common stock that the holder can own at any time upon conversion to an aggregate of 4.99% of our then issued and outstanding shares of common stock.

Series B Redeemable Convertible Preferred Stock

The Series B Preferred Stock has dividend rights that accrue at an annual rate of 6% until such Series B Preferred is no longer outstanding either due to conversion, redemption or otherwise. The Series B Preferred Stock also has liquidation rights equal to the original issue price of such shares and are payable upon our liquidation, dissolution or winding up, either voluntary or involuntary. Each outstanding share of Series B Preferred Stock is entitled to one vote on all stockholder matters to come before our stockholders and are not entitled to series voting except as required by law.

Each share of Series B Preferred Stock is convertible, at the option of the holder, into that number of fully-paid, nonassessable shares of common stock determined by dividing the Original Issue Price for the Series B Preferred ($25.00, as may be adjusted for recapitalizations) by the Conversion Price ($87.50, as may be adjusted for recapitalizations). Each share of Series B Preferred Stock automatically converts into shares of common stock under certain conditions set forth in the certificate of designations for the Series B Preferred Stock.

Subject to the terms of any credit or debt agreements in place which prevent us from redeeming the Series B Preferred Stock for cash, we have the option, exercisable from time to time after the Original Issue Date, to redeem all or any portion of the outstanding shares of Series B Preferred Stock which have not been previously converted into common stock, by paying each applicable holder, an amount equal to (a) the Original Issue Price multiplied by the number of shares of Series B Preferred Stock held by each applicable holder, subject to such redemption; plus (b) the accrued dividends on such shares.

The consent of a majority in interest of the Series B Preferred Stock must also be obtained prior to certain corporate actions.

Series C Redeemable Convertible Preferred Stock

Holders of the Series C Preferred Stock are entitled to cumulative dividends in the amount of 6.0% per annum, payable upon redemption, conversion, or maturity, and when, as and if declared by our Board of Directors in its discretion. The Series C Preferred Stock ranks senior to the common stock and pari passu with respect to our Series B Preferred Stock.  The Series C Preferred Stock has no right to vote on any matters, questions or proceedings of the Company including, without limitation, the election of directors except: (a) during a period where a dividend (or part of a dividend) is in arrears; (b) on a proposal to reduce the Company’s share capital; (c) on a resolution to approve the terms of a buy-back agreement; (d) on a proposal to wind up the Company; (e) on a proposal for the disposal of all or substantially all the Company’s property, business and undertaking; and (f) during the winding-up of the Company.

The Series C Preferred Stock may be converted into shares of common stock at any time at the option of the holder, or at our option if certain equity conditions (as defined in the certificate of designation for the Series C Preferred Stock), are met. Upon conversion, we will pay the holders of the Series C Preferred Stock being converted an amount, in cash or stock at our sole discretion, equal to the dividends that such shares would have otherwise earned if they had been held through the maturity date, and issue to the holders such number of shares of Common stock equal to $10,000 per share of Series C Preferred Stock (the “Face Value”) multiplied by the number of such shares of Series C Preferred Stock divided by the applicable Conversion Price (as defined in the certificate of designation for the Series C Preferred Stock).

 

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The conversion premium under the Series C Preferred Stock is payable and the dividend rate under the Series C Preferred Stock is adjustable. Specifically, the conversion rate of such premiums and dividends equals 95% of the average of the lowest 5 individual daily volume weighted average prices during the Measuring Period, not to exceed 100% of the lowest sales prices on the last day of the Measuring Period, less $0.05 per share of common stock, unless a triggering event has occurred, in which case the conversion rate equals 85% of the lowest daily volume weighted average price during the Measuring Period, less $0.10 per share of common stock not to exceed 85% of the lowest sales prices on the last day of such the Measuring Period, less $0.10 per share. The “Measuring Period” is the period beginning, if no trigger event has occurred, 30 trading days, and if a trigger event has occurred, 60 trading days, before the applicable notice has been provided regarding the exercise or conversion of the applicable security, and ending, if no trigger event has occurred, 30 trading days, and if a trigger event has occurred, 60 trading days, after the applicable number of shares stated in the initial exercise/conversion notice have actually been received into the Investor’s designated brokerage account in electronic form and fully cleared for trading (subject to certain extensions described in the applicable securities, which have been triggered to date). Because a trigger event has occurred under the Series C Preferred Stock and because certain requirements related to the termination of the Measuring Period are not met, and likely will never be met, the Measuring Period will likely continue indefinitely.

The Series C Preferred Stock has a maturity date that is seven years after the date of issuance and, if the Series C Preferred Stock has not been wholly converted into shares of common stock prior to such date, we may redeem the Series C Preferred Stock on such date by repaying to the investor in cash 100% of the Face Value plus an amount equal to any accrued but unpaid dividends thereon. 100% of the Face Value, plus an amount equal to any accrued but unpaid dividends thereon, automatically becomes payable in the event of a liquidation, dissolution or winding up by us.

We may not issue any other preferred stock (other than the Series B Preferred Stock) that is pari passu or senior to the Series C Preferred Stock with respect to any rights for a period of one year after the earlier of such date (i) a registration statement is effective and available for the resale of all shares of common stock issuable upon conversion of the Series C Preferred Stock, or (ii) Rule 144 under the Securities Act is available for the immediate unrestricted resale of all shares of common stock issuable upon conversion of the Series C Preferred Stock.

Dividend Policy

 

We have not declared or paid cash dividends or made distributions in the past. We do not anticipate that we will pay cash dividends or make distributions in the foreseeable future. We currently intend to retain and reinvest future earnings to finance operations. We may however declare and pay dividends in shares of our common stock in the future (similar to how we have in the past).

 

Recent Sales of Unregistered Securities

 

For the year ended March 31, 2018, the 408,508 outstanding shares of Series B Preferred Stock had accrued an aggregate of $453,573 in quarterly dividends ($153,191 each for the quarters ended June 30, 2017, September 30, 2017 and December 30, 2017). The Company paid the accrued dividends on February 5, 2018, by way of the issuance of an aggregate of 5,251 shares of our common stock to the preferred shareholders pursuant to the terms of the designation (which provides that the Shares shall be based on a value of $87.50 per share. As the issuance of the common stock in satisfaction of the dividends did not involve a “sale” of securities under Section 2(a)(3) of the Securities Act, we believe that no registration of such securities, or exemption from registration for such securities, is required under the Securities Act. Notwithstanding the above, to the extent such shares are deemed “sold or offered”, we claim an exemption from registration pursuant to Section 4(a)(2) and/or Rule 506(b) of Regulation D of the Securities Act, since the transaction did not involve a public offering, the recipients were “accredited investors”, and acquired the securities for investment only and not with a view towards, or for resale in connection with, the public sale or distribution thereof. The securities are subject to transfer restrictions, and the certificates evidencing the securities contain an appropriate legend stating that such securities have not been registered under the Securities Act and may not be offered or sold absent registration or pursuant to an exemption therefrom. The securities will not be registered under the Securities Act and such securities may not be offered or sold in the United States absent registration or an exemption from registration under the Securities Act and any applicable state securities laws. The 5,251 shares were issued to Richard N. Azar II, our then Chief Executive Officer and then director (1,369 shares), RAD2 Minerals, Ltd., which is owned and controlled by Mr. Azar (2,571 shares), Segundo Resources, LLC, which is owned and controlled by Mr. Azar (746 shares), and Alan Dreeben (565 shares).

 

 

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As of June 28, 2018, a total of approximately 4.9 million shares of common stock had been issued in connection with the exercise of the First Warrant. During the year ended March 31, 2018, approximately 3.9 million shares of common stock were issued and subsequent to March 31, 2018, approximately 450,000 shares of common stock were issued in connection with the First Warrant.

 

As of June 28, 2018, the Investor had converted 363 shares of Series C Preferred Stock into approximately 9.6 million shares of common stock and as of June 28, 2018, the Investor was still due approximately 9 million shares of common stock upon the conversion of the remaining 1,112 shares of Series C Preferred Stock sold in 2017 and 2016, subject to further adjustments pursuant to the terms of the Series C Preferred Stock, based on a conversion price of $1.23 per share for the Series C Preferred Stock sold in 2016 and $2.92 per share for the Series C Preferred Stock sold in 2017, which conversion prices may actually be significantly less than such estimate and which shares due upon conversion of such Series C Preferred Stock may be significantly greater, as of the date of this filing. The Investor is also due approximately 922,000 shares of common stock upon the conversion of the Debenture, based on a conversion price of $1.23 per share, which conversion price may actually be significantly less than such estimate and which shares due may be significantly greater, as of the date of this filing.

 

The sales and issuances of the securities described above have been determined to be exempt from registration under the Securities Act in reliance on Sections 3(a)(9) and 4(a)(2) of the Securities Act, Rule 506 of Regulation D promulgated thereunder and Regulation S promulgated thereunder, as transactions by an issuer not involving a public offering. The warrant holder/preferred stock holder has represented that it is an accredited investor, as that term is defined in Regulation D, it is not a U.S. Person, and that it is acquiring the securities for its own account.

 

In connection with the departure of Mr. Anthony C. Schnur as Chief Executive Officer and director of the Company effective June 2, 2017, the Company entered into a Severance Agreement and Release with Mr. Schnur (the “Release”), whereby (i) his employment agreement with the Company was terminated, (ii) he entered into a mutual release with the Company; (iii) the Company agreed to issue him 4,800 shares of unregistered common stock (to be issued in installments of 400 per month)(the “Settlement Shares”) and a monthly cash payment of $14,000 for twelve months; and (iv) he was granted reimbursement of the payment of his COBRA premiums through (a) the one year anniversary of the termination or (b) until he is eligible to participate in the health insurance plan of another employer, whichever is sooner, and provided that the amount of such health benefits shall reduce his monthly cash payment. On January 11, 2018, and effective as of the original date of the Release, the Company and Mr. Schnur entered into a First Amendment to Severance Agreement and Release (the “Release Amendment”), whereby the terms of the Release were changed to provide for among other things, the payment of $49,000 on or before January 12, 2018; $15,000 on or before the 15th of each month from February 2018 to July 2018; and $19,000 on or before August 15, 2018, and further provided for the issuance of the entire amount of the Settlement Shares within five days of the later of the date the Company’s stockholders approved the issuance of the Settlement Shares and the date the NYSE American approved the issuance of such shares. The Settlement Shares were issued in February 2018. The sales and issuances of the securities described above have been determined to be exempt from registration under the Securities Act in reliance on Section 4(a)(2) of the Securities Act and Rule 506 of Regulation D promulgated thereunder, as transactions by an issuer not involving a public offering.

 

As of March 31, 2018, the 408,508 outstanding shares of Series B Preferred Stock had accrued an aggregate of $153,191 in quarterly dividends. The Company paid the accrued dividends in May 2018, by way of the issuance of an aggregate of 1,751 shares of our common stock to the preferred shareholders pursuant to the terms of the designation (which provides that the Shares shall be based on a value of $87.50 per share. As the issuance of the common stock in satisfaction of the dividends did not involve a “sale” of securities under Section 2(a)(3) of the Securities Act, we believe that no registration of such securities, or exemption from registration for such securities, is required under the Securities Act. Notwithstanding the above, to the extent such shares are deemed “sold or offered”, we claim an exemption from registration pursuant to Section 4(a)(2) and/or Rule 506(b) of Regulation D of the Securities Act, since the transaction did not involve a public offering, the recipients were “accredited investors”, and acquired the securities for investment only and not with a view towards, or for resale in connection with, the public sale or distribution thereof. The securities are subject to transfer restrictions, and the certificates evidencing the securities contain an appropriate legend stating that such securities have not been registered under the Securities Act and may not be offered or sold absent registration or pursuant to an exemption therefrom. The securities will not be registered under the Securities Act and such securities may not be offered or sold in the United States absent registration or an exemption from registration under the Securities Act and any applicable state securities laws. The 1,751 shares were issued to Richard N. Azar II, our then Chief Executive Officer and then director (457 shares), RAD2 Minerals, Ltd., which is owned and controlled by Mr. Azar (856 shares), Segundo Resources, LLC, which is owned and controlled by Mr. Azar (249 shares), and Alan Dreeben (189 shares).

 

 

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On June 30, 2018, the 408,508 outstanding shares of Series B Preferred Stock will have accrued an aggregate of $153,191 in quarterly dividends. The Company plans to pay the dividend subsequent to the date of this filing, by way of the issuance of an aggregate of 1,751 shares of our common stock to the preferred shareholders pursuant to the terms of the designation (which provides that the Shares shall be based on a value of $87.50 per share. As the issuance of the common stock in satisfaction of the dividends will not involve a “sale” of securities under Section 2(a)(3) of the Securities Act, we believe that no registration of such securities, or exemption from registration for such securities, is required under the Securities Act. Notwithstanding the above, to the extent such shares are deemed “sold or offered”, we plan to claim an exemption from registration pursuant to Section 4(a)(2) and/or Rule 506(b) of Regulation D of the Securities Act, since the transaction will not involve a public offering, the recipients are “accredited investors”, and will acquire the securities for investment only and not with a view towards, or for resale in connection with, the public sale or distribution thereof. The securities will be subject to transfer restrictions, and the certificates evidencing the securities contain an appropriate legend stating that such securities have not been registered under the Securities Act and may not be offered or sold absent registration or pursuant to an exemption therefrom. The securities will not be registered under the Securities Act and such securities may not be offered or sold in the United States absent registration or an exemption from registration under the Securities Act and any applicable state securities laws. The 1,751 shares were issued to Richard N. Azar II, our then Chief Executive Officer and director (457 shares), RAD2 Minerals, Ltd., which is owned and controlled by Mr. Azar (856 shares), Segundo Resources, LLC, which is owned and controlled by Mr. Azar (249 shares), and Alan Dreeben (189 shares).

 

On October 5, 2017, the Company and the Investor entered into the October 2017 Purchase Agreement described in greater detail below underItem 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” – “Recent Securities and Stock Purchase Agreements”. On October 5, 2017, in connection with the entry into the October 2017 Purchase Agreement, the Investor purchased 212 shares of Series C Preferred Stock for $2 million (the “Initial Closing”); on November 21, 2017, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 106 shares of Series C Preferred Stock for $1 million (the “Second Closing”); on December 27, 2017, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Third Closing”); on January 31, 2018, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Fourth Closing”); on February 22, 2018, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Fifth Closing”); on March 9, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Sixth Closing”); on April 10, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Seventh Closing”); and on May 22, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Eighth Closing”).

 

The Sixth Closing, Seventh Closing and Eighth Closing occurred notwithstanding the terms of the October 2017 Purchase Agreement which required the sixth closing to be for a total of $5 million (the “$5 Million Closing”), as the parties mutually agreed to the sales of only $1 million of Series C Preferred Stock to be sold pursuant to the $5 Million Closing, at the Sixth Closing, Seventh Closing and Eighth Closing.

 

The Company plans to use the proceeds from the sale of the Series C Preferred Stock for working capital, workovers on existing wells, drilling and completion of additional wells, acquisitions, repayment of vendor balances and payments to IBC, in anticipation of regaining compliance.

 

The sale and issuance of the securities have been determined to be exempt from registration under the Securities Act in reliance on Sections 3(a)(9) and 4(a)(2) of the Securities Act, Rule 506 of Regulation D promulgated thereunder and Regulation S promulgated thereunder, as transactions by an issuer not involving a public offering. The Investor has represented that it is an accredited investor, as that term is defined in Regulation D. The Investor also has represented that it is acquiring the securities for investment purposes only and not with a view to or for sale in connection with any distribution thereof.

 

 

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As of the date of this report, the 948 shares of Series C Preferred Stock sold under the October 2017 Purchase Agreement to date would convert into approximately 5.8 million shares of our common stock if fully converted, which number includes 116,677 shares of common stock convertible upon conversion of each such share of outstanding Series C Preferred Stock at a conversion price of $81.25 per share (based on the $10,000 face amount of the Series C Preferred Stock) and approximately 5,678,000 shares of common stock for premium shares due thereunder, which number of premium shares may increase from time to time as the trading price of our common stock decreases or upon the occurrence of any trigger event under the Designation of the Series C Preferred Stock, as described in greater detail in the Designation of the Series C Preferred Stock, based on a conversion price of $2.92 per share, which conversion price may actually be significantly less than such estimate and which shares due may be significantly greater, as of the date of this filing.

 

On December 7, 2017, we mistakenly issued 64,000 shares of common stock due upon exercise of certain warrants, of which 32,000 shares were cancelled during the year ended March 31, 2018 and the remaining 32,000 shares were cancelled subsequent to March 31, 2018.

 

ITEM 6. SELECTED FINANCIAL DATA.

 

Not required under Regulation S-K for “smaller reporting companies.”

 

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

 

General

 

The following is a discussion by management of its view of the Company’s business, financial condition, and corporate performance for the past year. The purpose of this information is to give management’s recap of the past year, and to give an understanding of management’s current outlook for the near future. This section is meant to be read in conjunction with “Item 8. Financial Statements and Supplementary Data” of this Annual Report on Form 10-K.

 

Our fiscal year ends on the last day of March of the calendar year. We refer to the years ended March 31, 2018 and 2017 as our 2018 and 2017 fiscal years, respectively.

 

Recent Securities and Stock Purchase Agreements

 

On October 5, 2017, the Company and the Investor entered into the October 2017 Purchase Agreement, pursuant to which (1) the Investor purchased 212 shares of Series C Preferred Stock on the closing date of the agreement, October 4, 2017 (the “Initial Closing”), for $2 million, and agreed, subject to certain closing conditions set forth in the agreement, agreed to purchase (2) 106 shares of Series C Preferred Stock for $1,000,000, 10 days after the Initial Closing (which closing occurred on November 21, 2017); (3) 105 shares of Series C Preferred Stock for $1,000,000, 10 days after the second closing (which closing occurred on December 27, 2017); (4) 105 shares of Series C Preferred Stock for $1,000,000, 10 days after the third closing (which closing occurred on January 30, 2018); (5) 105 shares of Series C Preferred Stock for $1,000,000, 10 days after the fourth closing; (6) 525 shares of Series C Preferred Stock for $5,000,000, 30 days after the fifth closing; and (7) 525 shares of Series C Preferred Stock for $5,000,000, 30 days after the sixth Closing.

 

On October 5, 2017, in connection with the entry into the October 2017 Purchase Agreement, the Investor purchased 212 shares of Series C Preferred Stock for $2 million (the “Initial Closing”); on November 21, 2017, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 106 shares of Series C Preferred Stock for $1 million (the “Second Closing”); on December 27, 2017, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Third Closing”); on January 31, 2018, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Fourth Closing”); on February 22, 2018, pursuant to the terms of the October 2017 Purchase Agreement, we sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Fifth Closing”); on March 9, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Sixth Closing”); on April 10, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Seventh Closing”); and on May 22, 2018, the Company sold the Investor an additional 105 shares of Series C Preferred Stock for $1 million (the “Eighth Closing”).

 

 

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The Sixth Closing, Seventh Closing and Eighth Closing occurred notwithstanding the terms of the October 2017 Purchase Agreement which required the sixth closing to be for a total of $5 million (the “$5 Million Closing”), as the parties mutually agreed to the sales of only $1 million of Series C Preferred Stock to be sold pursuant to the $5 Million Closing, at the Sixth Closing, Seventh Closing and Eighth Closing.

 

On March 2, 2018, the Company and the Investor entered into an amendment to the October 2017 Purchase Agreement (the “Amendment”), pursuant to which the Investor (a) waived any and all Trigger Events (as defined in the certificate of designation of the Series C Preferred Stock (the “Designation”)) that had occurred prior to March 2, 2018, (b) agreed that all calculations provided for in the Designation would be made as if no such Trigger Event had occurred, and (c) waived any right to receive any additional shares of common stock based upon any such Trigger Event, with respect to all shares of Series C Preferred Stock, other than any which have already been converted.

 

The Investor also agreed, pursuant to the Amendment, that the conversion rate of conversion premiums pursuant to the Designation would remain 95% of the average of the lowest 5 individual daily volume weighted average prices during the applicable Measuring Period (as defined in the Designation), not to exceed 100% of the lowest sales prices on the last day of the Measuring Period, less $0.05 per share of common stock, unless a triggering event has occurred, and that such $0.05 per share discount would not be adjusted in connection with the Company’s previously reported 1-for-25 reverse stock split affected on March 5, 2018.

 

The Company plans to use the proceeds from the sale of the Series C Preferred Stock for working capital, workovers on existing wells, drilling and completion of additional wells, acquisitions, repayment of vendor balances and payments to IBC, in anticipation of regaining compliance.

 

On August 2, 2017, and effective June 13, 2017, the Company entered into an agreement with Vantage Fund, LLC (“Vantage” and the “Vantage Agreement”), pursuant to which Vantage agreed to provide up to $6 million of funding to the Company, in the sole discretion of Vantage, with $400,000 provided in the initial tranche (the “Initial Tranche”). The consideration for the Initial Tranche of funding was the assignment to Vantage of all of the Company’s rights and ownership in its wholly-owned subsidiary Camber Permian II, LLC (“Camber Permian”) which included leaseholds and potential participation rights in undeveloped oil and gas property known as Arrowhead. The Vantage Agreement contained customary indemnification requirements. On July 17, 2017, Vantage provided $120,000 to the Company under the Vantage Note and on July 20, 2017, Vantage provided $30,000 to the Company under the Vantage Note. Vantage was granted a second lien on the Jackrabbit property in connection with the financing. On November 9, 2017, in connection with the sale of the Jackrabbit Acreage, the Company paid Vantage the full amount due on the Vantage Note of $150,000.

 

Operations

 

Camber’s objective for our current producing wells is to operate as efficiently as possible, look for technological advancements to increase the life of the wells, evaluate the economic viability of these wells and consider adding to or working over our low producing assets. During fiscal 2018, we completed numerous workovers in the Coyle (Hunton) Field and initiated workovers in the Okfuskee County, Oklahoma Field. Costs associated with producing oil, natural gas and NGLs are substantial. Some of these costs vary with commodity prices, some trend with the type and volume of production, and others are a function of the number of wells we own and operate. Production expenses are the costs incurred in the operation of productive properties and workover costs. Expenses for utilities, direct labor, water transportation, injection and disposal, materials and supplies comprise the most significant portion of our production expenses. Certain items, such as direct labor and materials and supplies, generally remain relatively fixed across broad production volume ranges, but can fluctuate depending on the activities performed during a given period. We monitor our operations to ensure that we are incurring production expenses at an acceptable level. For example, we monitor our production expenses per Boe to determine if any wells or properties should be shut in, recompleted or sold. This unit rate also allows us to monitor these costs to identify trends and to benchmark against other producers. Although we strive to reduce our production expenses, these expenses can increase or decrease on a per unit basis as a result of various factors as we operate our properties or make acquisitions and dispositions of properties.

 

For the year ended March 31, 2018, the Company produced oil, natural gas and NGLs at an average of approximately 842 net barrels of oil equivalent per day (Boepd) from wells in four Texas counties and three Oklahoma counties in the Mid-Continent region. The Company operates 34 gross wells as of the date of this filing. The total number of gross wells is 174, with the active producers being 86. The ratio between the gross and net production differs due to varied working interests and net revenue interests in each well. As we develop our properties, we may see the opportunity to increase our natural gas and natural gas liquids production.

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Reserves

 

Camber’s estimated total net proved and probable reserves as of March 31, 2018 were 3,480,380 barrels of crude oil and NGL combined and 16,868,360 Mcf of natural gas which translates to an equivalent of 6.29 million BOE. The total net proved reserves are 1,565,280 barrels of crude oil and NGL combined and 8,147,170 Mcf of natural gas which translates to an equivalent of 2.92 million BOE and the total net probable reserves are 1,915,100 barrels of crude oil and NGL combined and 8,721,190 Mcf of natural gas which translates to an equivalent of 3.36 million BOE. These reserves are based on the Oil and Gas Benchmark Prices to Estimate Year-End Petroleum Reserves and Values Using U.S. Securities and Exchange Commission Guidelines from the Modernization of Oil and Gas Reporting and on the quantities of oil, natural gas and NGLs, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible from a given date forward from known reservoirs under existing economic conditions, operating methods and government regulations prior to the time at which contracts providing the rights to operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation. Reserves and economic evaluation of all of our properties are prepared on a well-by-well basis. The accuracy of the reserve estimates is a function of the quality and quantity of available data; interpretation of that data; accuracy of various mandated economic assumptions; and judgement of the independent reserve engineer.

 

Using the average monthly crude oil price of $50.63 per Bbl and natural gas price of $2.53 per thousand cubic feet (Mcf) for the twelve months ended March 31, 2018, our estimated discounted future net cash flow (“PV-10”) before tax expenses for our total proved reserves was approximately $7.5 million. Total reserve value at March 31, 2018 represents a decrease of approximately $8.5 million or 53% from a year earlier using the same SEC pricing and reserves methodology. The decrease is primarily due to the Rogers foreclosure and natural declines in the production of our oil and gas properties. Oil, natural gas and NGL prices are market driven and have been historically volatile, and we expect that future prices will continue to fluctuate due to supply and demand factors, seasonality, and geopolitical and economic factors, and such volatility can have a significant impact on our estimates of proved reserves and the related PV-10 value.

 

The reserves as of March 31, 2018 were determined in accordance with standard industry practices and SEC regulations by the licensed independent petroleum engineering firm of Graves & Co. Consulting LLC. Oil, natural gas and NGL reserve estimates require significant judgments in the evaluation of all available geological, geophysical, engineering and economic data. The data for a given field may change substantially over time as a result of numerous factors including, but not limited to, additional development activity, production history, projected future production, economic assumptions relating to commodity prices, operating expenses, severance and other taxes, capital expenditures and remediation costs and these estimates are inherently uncertain. If estimates of proved reserves decline, our depreciation, depletion and amortization (“DD&A”) rate will increase, resulting in a decrease in net income. A decline in estimates of proved reserves could also cause us to perform an impairment analysis to determine if the carrying amount of oil and natural gas properties exceeds fair value and could result in an impairment charge, which would reduce earnings. Although these hydrocarbon quantities have been determined in accordance with industry standards, they are prepared using the subjective judgments of the independent engineers, and may actually be more or less.

 

Oil and Gas Revenue

 

During the year ended March 31, 2018, our net crude oil sales volumes decreased to 27,704 Bbls from 32,918 Bbls, a 16% decrease over the previous fiscal year. The production decrease is primarily related to the effects of the Rogers foreclosure, described in greater detail above under “Part I” – “Item 1. Business” - “Recent Events” - “Rogers Loan Default and Foreclosure”.

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Major Expenditures

 

The table below sets out the major components of our operating and corporate expenditures for the years ended March 31, 2018 and 2017:

 

   2018  2017
Additions to Oil and Gas Properties (Capitalized)          
Acquisitions Using Cash  $460,000   $—   
Other Capitalized Costs (a)   1,581,655    3,445,566 
     Subtotal   2,041,655    3,445,566 
Segundo Acquisition          
Cash Paid   —      4,975,000 
ARO Assumed   —      755,862 
Account Receivable Assumed   —      (635,482)
Debt Assumed   —      30,595,256 
Preferred Stock Issued   —      14,898,038 
Common Stock Issued   —      49,176,530 
Impairment   —      (48,990,520)
     Subtotal   —      50,774,684 
Total Additions (Deductions) to Oil and Gas Properties   2,041,655    54,220,250 
Lease Operating Expenditures (Expensed)   4,874,724    3,261,082 
Severance and Property Taxes (Expensed)   300,314    256,263 
   $7,216,693   $57,737,595 
           
General and Administrative Expense (Cash based)  $5,979,586   $3,929,274 
Share-Based Compensation (Non-Cash)   1,194,243    114,874 
Total General and Administrative Expense  $7,173,829   $4,044,148 

 

(a)Other capitalized costs include title related expenses and tangible and intangible drilling costs.

 

Market Conditions and Commodity Prices

 

Our financial results depend on many factors, particularly the price of natural gas and related natural gas liquids, and crude oil and our ability to market our production on economically attractive terms. Commodity prices are affected by many factors outside of our control, including changes in market supply and demand, which are impacted by weather conditions, inventory storage levels, basis differentials and other factors. As a result, we cannot accurately predict future commodity prices and, therefore, we cannot determine with any degree of certainty what effect increases or decreases in these prices will have on our production volumes or revenues. In addition to production volumes and commodity prices, finding and developing sufficient amounts of natural gas and crude oil reserves at economical costs are critical to our long-term success. We expect prices to remain volatile for the remainder of the year. For information about the impact of realized commodity prices on our natural gas and crude oil and condensate revenues, refer to “Results of Operations” below.

Results of Operations

 

The following discussion and analysis of the results of operations for each of the two fiscal years in the period ended March 31, 2018 should be read in conjunction with the financial statements of Camber Energy, Inc. and notes thereto (see “Item 8. Financial Statements and Supplementary Data”). As used below, the abbreviations “Bbls” stands for barrels, “Mcf” for thousand cubic feet and “Boe” for barrels of oil equivalent (determined under the relative energy content method by using a ratio of 6.0 Mmbtu (1 million British Thermal Units) to 1.0 Bbl of oil).

 

We reported a net loss for the year ended March 31, 2018 of $24.8 million, or ($10.69) per share. For the year ended March 31, 2017, we reported a net loss of $89.1 million, or ($173.41) per share. The decrease in net loss was primarily due to the recognition of a substantial impairment of oil and gas properties in prior period and higher operating revenues during the current period, as discussed in greater detail below.

 

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Net Operating Revenues

 

The following table sets forth the revenue and production data for the years ended March 31, 2018 and 2017.

 

       Increase  %
   2018  2017  (Decrease)  Incr (Decr)
Sale Volumes:                    
Crude Oil (Bbls)   27,704    36,331    (8,627)   (24%)
Natural Gas (Mcf)   796,384    546,644    249,740    46%
NGL (Gallons)   6,177,153    4,095,651    2,081,502    51%
Total (Boe)   307,510    224,954    82,556    37%
                     
Crude Oil  (Bbls per day)   76    100    (24)   (24%)
Natural Gas (Mcf per day)   2,182    1,498    684    46%
NGL (Gallons per day)   16,924    11,221    5,703    51%
Total (Boe per day)   842    617    225    36%
                     
Average Sale Price:                    
Crude Oil ($/Bbl)  $43.26   $45.54   $(2.28)   (5%)
Natural Gas($/Mcf)   2.58    2.99    (0.41)   (14%)
NGL ($/Bbl)   0.58    0.49    0.09    18%
                     
                     
Net Operating Revenues:                    
Crude Oil  $1,198,514   $1,654,589   $(456,075)   (28%)
Natural Gas   2,051,846    1,636,212    415,634    25%
NGL   3,609,407    2,011,223    1,598,184    79%
          Total Revenues  $6,859,767   $5,302,024   $1,577,743    29%

 

Total crude oil and natural gas revenues for the year ended March 31, 2018 increased $1.58 million, or 29%, to approximately $6.9 million compared to $5.3 million for the same period a year ago due primarily to the increase in sales volume.

 

 

 60 
 

 

Operating and Other Expenses

 

The following table sets forth operating and other expenses for the years ended March 31, 2018 and 2017:

 

           %
   2018  2017  Increase
(Decrease)
  Increase
(Decrease)
Direct lease operating expense  $4,601,156   $1,620,756   $2,980,400    184%
Workovers expense   273,568    538,960    (265,392)   (49%)
Other   —      1,101,366    (1,101,366)   (100%)
Total Lease Operating Expenses   4,874,724    3,261,082    1,613,642    49%
Severance and Property Taxes   300,314    256,263    44,051    17%
Depreciation, Depletion,                    
Amortization and Accretion   1,480,535    2,698,738    (1,218,203)   (45%)
                     
Impairment of Oil and Gas Properties   8,137,987    79,142,113    (71,004,126)   (90%)
Loss on Sale of Property and Equipment   3,559,083        3,559,083    100%
General and Administrative (Cash)   5,979,586    3,929,274    2,050,312    52%
Share-Based Compensation (Non-Cash)   1,194,243    114,874    1,079,369    940%
Total General and Administrative Expense  $7,173,829   $4,044,148   $3,129,681    77%
Interest Expense  $6,018,829   $3,165,151   $2,853,678    90%
Other Expense, Net  $86,054   $1,872,768   $(1,786,714)   (95%)

 

Lease Operating Expenses. Lease operating expenses can be divided into the following categories: costs to operate and maintain Camber’s crude oil and natural gas wells, the cost of workovers and lease and well administrative expenses. Operating and maintenance expenses include, among other things, pumping services, salt water disposal, equipment repair and maintenance, compression expense, lease upkeep and fuel and power. Workovers are operations to restore or maintain production from existing wells. Each of these categories of costs individually fluctuates from time to time as Camber attempts to maintain and increase production while maintaining efficient, safe and environmentally responsible operations. The costs of services charged to Camber by vendors, fluctuate over time.

 

In total, the overall lease operating expenses increased $1.6 million or 49% for the current period as compared to the prior year’s period due in part to increased sales volumes.

 

Depreciation, Depletion, Amortization and Accretion (“DD&A”). DD&A, related to proved oil and gas properties is calculated using the unit-of-production method. Under full cost accounting, the amortization base is comprised of the total capitalized costs and total future investment costs associated with all proved reserves.

 

DD&A decreased for the current year as compared to the prior year period by $1.2 million or 45% primarily related to the decrease in total depreciable assets caused by the Release with Rogers.

 

Impairment of Oil and Gas Properties. During the year ended March 31, 2018, the Company recorded impairments totaling $8.1 million primarily related to unproved properties due to expirations of leaseholds. During the year ended March 31, 2017, the Company recorded impairments totaling $79.1 million, which represented $10.9 million related to proved properties, $18.7 million related to unproved properties, and $49.5 million in conjunction with the Acquisition, primarily due to continued low commodity prices during the fiscal year.

 

Loss on Sale of Property and Equipment. During the year ended March 31, 2018, the Company recorded a loss on sale of property and equipment of $3,559,083. During the year ended March 31, 2017, the Company recorded a loss on sale of property and equipment of $-0-.

 

General and Administrative Expenses (“G&A”) (excluding share-based compensation). G&A expenses for the current period increased by approximately $2.1 million or 52% primarily related to professional fees from our financing transactions, and consulting, investor relations, and marketing expenses.

 

Share-Based Compensation. Share-based compensation, which is included in General and Administrative expenses in the Statements of Operations increased approximately $1.1 million or 940% for the year ended March 31, 2018, as compared to the prior year primarily due to shares granted to consultants as compensation for services performed for the Company. Share-based compensation is utilized for the purpose of conserving cash resources for use in field development activities and operations.

 

 

 61 
 

 

Interest Expense. Interest expense for the year ended March 31, 2018 increased by $2.8 million or 90%, when compared to the prior year primarily due to the approximate $2.1 million of default interest related to the Rogers Foreclosure, additional interest payments on the IBC Loan (which was only outstanding for part of the year ended March 31, 2017) and the amortization of various loan discounts for outstanding and recently retired payables.

 

Other Expense. Other expense for the year ended March 31, 2018 decreased by approximately $1.8 million when compared to the prior period primarily due to the settlement of costs incurred in the prior year related to the Acquisition.

 

LIQUIDITY AND CAPITAL RESOURCES

 

The accompanying consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business. Accordingly, the financial statements do not include any adjustments relating to the recoverability of assets and classification of liabilities that might be necessary should the Company be unable to continue as a going concern.

 

Our primary sources of cash for the year ended March 31, 2018 were from funds generated from the sale of preferred stock, the sale of natural gas and crude oil production and funds borrowed under funding agreements. The primary uses of cash were funds used in operations.

 

Working Capital

 

At March 31, 2018, the Company's total current liabilities of $40.0 million exceeded its total current assets of approximately $1.7 million, resulting in a working capital deficit of $38.3 million, while at March 31, 2017, the Company's total current liabilities of $48.2 million exceeded its total current assets of $3.9 million, resulting in a working capital deficit of $44.3 million. The $6 million decrease in the working capital deficit is primarily related to the settlement of the debt related to the Rogers Loan, described in greater detail above under "Part I" - "Item 1. Business" - "Recent Events" - "Rogers Loan Default and Foreclosure".

 

Financing

 

A summary of our financing transactions, the Rogers Loan (which has now been satisfied) and other recent funding transactions can be found under below under “Part II” - “Item 8. Financial Statements and Supplementary Data” - “Note 2 – Liquidity and Going Concern Considerations” and “Note 6 – Notes Payable and Debenture”, and the Debenture, First Warrant and Series C Preferred Stock are described in greater detail under “Part II” - “Item 8. Financial Statements and Supplementary Data” – “Note 10 – Stockholders’ Equity (Deficit)”.

 

Additionally, due to our current capital structure and the nature of oil and gas interests, i.e., that rates of production generally decline over time as oil and gas reserves are depleted, if we are unable to obtain the necessary financing to finalize the asset purchase or drill additional wells and develop our PUDs; coupled with the continued substantial drop in commodity prices over the last twelve months, we believe that our revenues will continue to decline over time. Therefore, we may be forced to scale back our business plan, sell assets to satisfy outstanding debts or take other remedial steps which may include seeking bankruptcy protection.

 

Our limited cash position and significant liabilities raise substantial doubt about our ability to continue as a going concern for the next twelve months following the issuance of these financial statements. The accompanying financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business. Accordingly, the financial statements do not include any adjustments relating to the recoverability of assets and classification of liabilities that might be necessary should the Company be unable to continue as a going concern.

 

 

 62 
 

  

Cash Flows

 

  Year Ended March 31,
  2018  2017
Cash flows used in operating activities  $(5,766,104)  $(6,393,208)
Cash flows used in investing activities   (123,112)   (8,851,847)
Cash flows provided by financing activities   5,944,299    15,752,627 
Net increase in cash  $55,083   $507,572 

 

Net cash used in operating activities was $5.8 million for the year ended March 31, 2018 as compared to $6.4 million for the same period a year ago. The decrease in net cash used in operating activities of approximately $0.6 million was due primarily to an increase in operating cash including collections of receivables and increases in accounts payable and accrued expenses.

 

Net cash used in investing activities was $0.1 million for the year ended March 31, 2018, as compared to net cash used in investing activities of $8.9 million for the same period a year ago. The decrease in net cash used in investing activities of $8.8 million was primarily due to the decline in property additions, particularly related the Acquisition which were completed during the year ended March 31, 2017.

 

Net cash provided by financing activities was $5.9 million for the year ended March 31, 2018, and $15.8 million for the year ended March 31, 2017. The $9.9 million decrease in net cash provided by financing activities was mainly due primarily to the proceeds from debt and warrants offset by debt repayments in the prior year.

 

Off-Balance Sheet Arrangements

 

Camber does not participate in financial transactions that generate relationships with unconsolidated entities or financial partnerships. As of March 31, 2018, we did not have any off-balance sheet arrangements.

 

Critical Accounting Policies and Estimates

 

Camber prepares its financial statements and the accompanying notes in conformity with accounting principles generally accepted in the United States of America, which require management to make estimates and assumptions about future events that affect the reported amounts in the financial statements and the accompanying notes. Camber identifies certain accounting policies as critical based on, among other things, their impact on the portrayal of Camber’s financial condition, results of operations or liquidity, and the degree of difficulty, subjectivity and complexity in their deployment. Critical accounting policies cover accounting matters that are inherently uncertain because the future resolution of such matters is unknown. Management routinely discusses the development, selection and disclosure of each of the critical accounting policies. Following is a discussion of Camber’s most critical accounting policies:

 

Proved Oil and Natural Gas Reserves

 

Camber’s independent petroleum consultants estimate proved oil and gas reserves, which directly impact financial accounting estimates, including depreciation, depletion and amortization. Proved reserves represent estimated quantities of crude oil and condensate, natural gas liquids and natural gas that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under economic and operating conditions existing at the time the estimates were made. The process of estimating quantities of proved oil and gas reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions (upward or downward) to existing reserve estimates may occur from time to time. For related discussion, see “Item 1A. Risk Factors”.

 

 

 63 
 

 

Full Cost Accounting Method

 

Camber uses the full cost method of accounting for oil and gas producing activities. Costs to acquire mineral interests in oil and gas properties, to drill and equip exploratory wells used to find proved reserves, and to drill and equip development wells including directly related overhead costs and related asset retirement costs are capitalized.

 

Under this method, all costs, including internal costs directly related to acquisition, exploration and development activities are capitalized as oil and gas property costs on a country-by-country basis. Properties not subject to amortization consist of exploration and development costs, which are evaluated on a property-by-property basis. Amortization of these unproved property costs begins when the properties become proved or their values become impaired. Camber assesses overall values of unproved properties, if any, on at least an annual basis or when there has been an indication that impairment in value may have occurred. Impairment of unproved properties is assessed based on management’s intention with regard to future development of individually significant properties and the ability of Camber to obtain funds to finance their programs. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is added to the capitalized costs to be amortized. Costs of oil and gas properties are amortized using the units of production method. Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. 

 

Full Cost Ceiling Test Limitation

 

In applying the full cost method, Camber performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the “estimated present value,” of its proved reserves discounted at a 10% interest rate of future net revenues, based on current economic and operating conditions at the end of the period, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties. If capitalized costs exceed this limit, the excess is charged as an impairment expense.

 

Share-Based Compensation

 

In accounting for share-based compensation, judgments and estimates are made regarding, among other things, the appropriate valuation methodology to follow in valuing stock compensation awards and the related inputs required by those valuation methodologies. Assumptions regarding expected volatility of Camber’s common stock, the level of risk-free interest rates, expected dividend yields on Camber’s stock, the expected term of the awards and other valuation inputs are subject to change. Any such changes could result in different valuations and thus impact the amount of share-based compensation expense recognized in the Statements of Operations.

 

Revenue Recognition

 

Camber recognizes oil and natural gas revenue under the sales method of accounting for its interests in producing wells as crude oil and natural gas is produced and sold from those wells. Costs associated with production are expensed in the period incurred. Crude oil produced but remaining as inventory in field tanks is not recorded in Camber’s financial statements.

 

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

 

Pursuant to Item 305(e) of Regulation S-K (§ 229.305(e)), the Company is not required to provide the information required by this Item as it is a “smaller reporting company,” as defined by Rule 229.10(f)(1).

 

ITEM 8.  FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.

 

Our financial statements as of March 31, 2018 and 2017 and for the fiscal years ended March 31, 2018 and 2017 have been audited by GBH CPAs, PC, independent registered public accounting firms, and have been prepared in accordance with generally accepted accounting principles pursuant to Regulation S-X.

 

 

 64 
 

 

INDEX TO THE FINANCIAL STATEMENTS

     
    Page
Report of Independent Registered Public Accounting Firm    F-1
Consolidated Balance Sheets as of March 31, 2018 and 2017    F-2
Consolidated Statements of Operations for the Years Ended March 31, 2018 and 2017    F-3
Consolidated Statement of Changes in Stockholders’ Equity (Deficit) for the Years Ended March 31, 2018 and 2017    F-4
Consolidated Statements of Cash Flows for the Years Ended March 31, 2018 and 2017    F-5
Notes to Consolidated Financial Statements    F-6

 

 

 65 
 

 

 

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

 

 

To the stockholders and the board of directors of

Camber Energy, Inc.

San Antonio, Texas

 

Opinion on the Financial Statements

 

We have audited the accompanying consolidated balance sheets of Camber Energy, Inc. (the “Company”) as of March 31, 2018 and 2017, the related consolidated statements of operations, changes in stockholders’ equity (deficit), and cash flows for each of the years then ended, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of March 31, 2018 and 2017, and the results of its operations and its cash flows for each of 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 the 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.

 

Other matters

 

The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 2 to the financial statements, the Company has incurred significant losses from operations and had a working capital deficit as of March 31, 2018. These factors raise substantial doubt about its ability to continue as a going concern. Management's plans in regard to these matters are also described in Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.

 

 

/s/ GBH CPAs, PC

 

We have served as the Company's auditor since 2015.

 

GBH CPAs, PC
www.gbhcpas.com
Houston, Texas
July 2, 2018

 

 F-1 

 

 

CAMBER ENERGY, INC.
CONSOLIDATED BALANCE SHEETS
As of March 31,  2018  2017
ASSETS      
Current Assets          
Cash  $760,317   $705,234 
Restricted Cash   28,834    1,684,527 
Accounts Receivable   646,891    1,218,251 
Inventories   —      202,677 
Other Current Assets   228,733    119,995 
      Total Current Assets   1,664,775    3,930,684 
Property and Equipment          
Oil and Gas Properties - Subject to Amortization   61,082,526    73,791,362 
Oil and Gas Properties - Not Subject to Amortization   28,016,989    28,947,400 
Other Property and Equipment   1,570    441,201 
Total Property and Equipment   89,101,085    103,179,963 
Accumulated Depletion, Depreciation, Amortization and Impairment   (76,555,506)   (67,398,804)
      Total Property and Equipment, Net   12,545,579    35,781,159 
Other Assets   57,510    146,369 
Total Assets  $14,267,864   $39,858,212 
LIABILITIES AND STOCKHOLDERS' DEFICIT          
Current Liabilities          
Accounts Payable  $2,972,261   $3,094,131 
Common Stock Payable   200,000    59,471 
Accrued Expenses   1,140,730    778,736 
Notes Payable, Net of Discount   —      1,229,021 
Current Portion of Long-Term Notes Payable, Net of Discount   35,691,567    43,052,628 
Total Current Liabilities   40,004,558    48,213,987 
Long-term Notes Payable, Net of Discount   247,403    145,695 
Asset Retirement Obligation   979,159    2,045,847 
Derivative Liability   5    21,662 
Total Liabilities   41,231,125    50,427,191 
Commitments and Contingencies (see Note 8)          
Stockholders' Deficit          
Preferred Stock Series A, 2,000 Shares Authorized of          
 $0.001 Par Value, -0- and 500 Shares issued and Outstanding, respectively   —      —   
Preferred Stock Series B, 600,000 Shares Authorized of          
 $0.001 Par Value, 408,508 and 552,000 Shares issued and Outstanding, respectively   409    552 
Preferred Stock Series C, 500,000 Shares Authorized of          
 $0.001 Par Value, 1,132 and 404 Shares issued and Outstanding, respectively   1    1 
Common Stock, 500,000,000 Shares Authorized of $0.001 Par Value,          
5,758,970 and 1,084,637 Shares Issued and Outstanding, respectively   5,759    1,085 
Additional Paid-in Capital   141,424,282    134,920,767 
Stock Dividends Distributable   2,467,910    598,650 
Accumulated Deficit   (170,861,622)   (146,090,034)
        Total Stockholders' Deficit   (26,963,261)   (10,568,979)
Total Liabilities and Stockholders' Deficit  $14,267,864   $39,858,212 

 

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

 

 F-2 
 

 

 

CAMBER ENERGY, INC.
CONSOLIDATED STATEMENTS OF OPERATIONS

 

For the Year Ended March 31,  2018  2017
Net Operating Revenues          
Crude Oil  $1,198,514   $1,654,589 
Natural Gas   2,051,846    1,636,212 
NGL   3,609,407    2,011,223 
    Total   6,859,767    5,302,024 
           
Operating Expenses          
Lease Operating Expenses   4,874,724    3,261,082 
Severance and Property Taxes   300,314    256,263 
Depreciation, Depletion, Amortization and Accretion   1,480,535    2,698,738 
Impairment of Oil and Gas Properties   8,137,987    79,142,113 
Loss on Sale of Property and Equipment   3,559,083     
General and Administrative   7,173,829    4,044,148 
    Total   25,526,472    89,402,344 
           
Operating Loss   (18,666,705)   (84,100,320)
           
Other Expense (Income)          
Interest Expense   6,018,829    3,165,151 
Other Expense, Net   86,054    1,872,768 
Total Other Expense   6,104,883    5,037,919 
           
Loss Before Income Taxes   (24,771,588)   (89,138,239)
Income Tax Benefit (Expense)   —      15,000 
Net Loss  $(24,771,588)  $(89,123,239)
           
Net Loss Per Common Share          
Basic and Diluted  $(10.69)  $(173.41)
           
Weighted Average Number of          
Common Shares Outstanding          
Basic and Diluted   2,318,266    513,951 

  

 

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

 

 F-3 
 

 

 

CAMBER ENERGY, INC.

Consolidated Statements of Changes in Stockholders’ Equity (Deficit)

 

 

Series A

Preferred Stock

  Series B
Preferred Stock

 

Series C

Preferred Stock
  Common Stock  Additional  Stock     Total
  Number    Number    Number    Number    Paid-In  Divided  Accumulated  Stockholders'
  Of Shares  Amount  Of Shares  Amount  Of Shares  Amount  Of Shares  Amount  Capital  Distributable  Deficit  (Deficit) Equity
Balances, March 31, 2016   500   $1    —     $—      —     $—      64,218   $64   $59,367,428   $—     $(56,966,795)  $2,400,698 
Common Shares issued for:                                                            
Warrants Exercised   —      —      —      —      —      —      200,000    200    4,072,300    —      —      4,072,500 
Stock-Based Compensation   —      —      —      —      —      —      1,646    2    95,605    —      —      95,607 
Restricted Share Offering   —      —      —      —      —      —      600    1    47,999    —      —      48,000 
Conversion of Series A Preferred Stock   (500)   (1)   —      —      —      —      800    1    —      —      —      —   
Conversion of Series C Preferred Stock   —      —      —      —      (123)   —      239,355    239    (239)   —      —      —   
Asset Acquisition   —      —      —      —      —      —      520,387    520    49,176,010    —      —      49,176,530 
Asset Acquisition Lender Shares   —      —      —      —      —      —      15,612    16    1,455,766    —      —      1,455,782 
Conversion of Debt   —      —      —      —      —      —      38,712    39    1,445,630    —      —      1,445,669 
Stock Dividends   —      —      —      —      —      —      3,307    3    (3)   —      —      —   
Stock Placement Fees   —      —      —      —      —      —      —      —      (145,535)   —      —      (145,535)
Issuance of Series B Preferred Stock   —      —      552,000    552    —      —      —      —      14,897,486    —      —      14,898,038 
Issuance of Series C Preferred Stock   —      —      —      —      527    1    —      —      4,485,954    —      —      4,485,955 
Amortization of Stock Options   —      —      —      —      —      —      —      —      19,266    —      —      19,266 
Discount on Notes   —      —      —      —      —      —      —      —      601,750    —      —      601,750 
Stock Dividends to be Issued   —      —      —      —      —      —      —      —      (598,650)   598,650    —      —   
Net Loss   —      —      —      —      —      —      —      —      —      —      (89,123,239)   (89,123,239)
Balances, March 31, 2017   —      —      552,000    552    404    1    1,084,637    1,085    134,920,767    598,650    (146,090,034)   (10,568,979)
                                                             
Common Shares issued for:                                                            
Conversion of Series B Preferred Stock   —      —      (143,492)   (143)   —      —      40,998    41    102    —      —      —   
Conversion of Series C Preferred Stock   —      —      —      —      (10)   —      409,749    410    (410)   —      —      —   
Stock Dividends   —      —      —      —      —      —      7,617    7    58,817    (58,824)   —      —   
Share-Based Compensation   —      —      —      —      —      —      225,095    225    1,017,589    —      —      1,017,814 
Warrants - Abeyance   —      —      —      —      —      —      3,909,500    3,910    (3,910)   —      —      —   
Conversion of Debenture   —      —      —      —      —      —      70,189    70    34,930    —      —      35,000 
Lender Shares   —      —      —      —      —      —      2,000    2    35,898    —      —      35,900 
Rounding Adjustment for Split   —      —      —      —      —      —      9,185    9    (9)   —      —      —   
Issuance of Series C Preferred Shares   —      —      —      —      738    —      —      —      7,000,000    —      —      7,000,000 
Stock Dividends to be Issued   —      —      —      —      —      —      —      —      (1,928,084)   1,928,084    —      —   
Warrants - Vantage   —      —      —      —      —      —      —      —      288,592    —      —      288,592 
Net Loss   —      —      —      —      —      —      —      —      —      —      (24,771,588)   (24,771,588)
Balances, March 31, 2018   —     $—      408,508   $409    1,132   $1    5,758,970   $5,759   $141,424,282   $2,467,910   $(170,861,622)  $(26,963,261)

 

  

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

 

 F-4 
 

  

CAMBER ENERGY, INC.
CONSOLIDATED STATEMENTS OF CASH FLOWS

 

For the Year Ended March 31,  2018  2017
Cash Flows from Operating Activities          
Net Loss  $(24,771,588)  $(89,123,239)
Adjustments to Reconcile Net Losses to Net Cash Used in Operating Activities:          
Depreciation, Depletion, Amortization and Accretion   1,480,535    2,698,738 
Impairment of Oil and Gas Properties   8,137,987    79,142,113 
Share-Based Compensation   1,194,243    114,874 
Amortization of Discount on Notes   1,124,396    1,585,103 
Bad Debt Expense   258,594    779,421 
Gain on settlement of Accounts Payable   —     (44,279)
Change in Fair Value of Derivative Liability   (21,657)   (105,298)
Loss on Sale of Property and Equipment   3,559,083    —   
Changes in Components of Working Capital and Other Assets:          
Accounts Receivable   312,766    (1,268,667)
Inventories   —     (7,680)
Other Current Assets   (108,738)   (63,190)
Accounts Payable and Accrued Expenses   3,068,275    (101,104)
Net Cash Used in Operating Activities   (5,766,104)   (6,393,208)
Investing Cash Flows          
Cash paid for Oil and Gas Property Development Costs   (2,046,057)   (3,768,344)
Cash Paid for Segundo Acquisition   —      (4,975,000)
Proceeds from Sale of Oil and Gas Properties   1,825,587    —   
Proceeds from Sale of Other Property and Equipment   10,069    —   
Cash Proceeds from (Paid for) Deposits   88,859   (87,653)
Cash Paid for Other Property and Equipment   (1,570)   (20,850)
Net Cash Used in  Investing Activities   (123,112)   (8,851,847)
Financing Cash Flows          
Proceeds from Issuance of Notes Payable   —      2,750,000 
Proceeds from the Exercise of Warrants   —      4,072,500 
Principal Repayments on Notes Payable   —      (1,500,000)
Proceeds from Issuance of Long-Term Notes Payable   —      41,550,000 
Principal Repayments on Long-Term Notes Payable   (2,861,394)   (33,925,766)
Proceeds from Issuance of Convertible Notes   —      150,000 
Proceeds from Issuance of Series C Preferred Stock and Warrants   7,000,000    5,000,000 
Bond Sinking Fund Deposit   —      (1,684,527)
Proceeds from Borrowings on Notes Payable   150,000    —   
Cash Released from Restricted Cash   1,655,693    —   
Stock Placement Fees Paid   —      (659,580)
Net Cash Provided by Financing Activities   5,944,299    15,752,627 
Increase in Cash   55,083    507,572 
Cash at Beginning of the Year   705,234    197,662 
Cash at End of the Year  $760,317   $705,234 

  

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

 

 F-5 
 

 

CAMBER ENERGY, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 

 

NOTE 1 – ORGANIZATION AND OPERATIONS OF THE COMPANY

 

Camber Energy Inc. (“Camber” or the “Company”) is an independent oil and gas company engaged in the development and acquisition of onshore properties in Texas and Oklahoma. The Company’s main operations are primarily located in the Hunton formation in Lincoln, Logan and Payne and Okfuskee Counties, in central Oklahoma, the Cline shale and upper Wolfberry shale in Glasscock County, Texas; and Hutchinson County, Texas.

 

During August 2017, the Company relocated its corporate headquarters from Houston, Texas to San Antonio, Texas.

 

Effective on January 10, 2018, the Company filed, with the Secretary of State of Nevada, a Certificate of Amendment to the Company’s Articles of Incorporation to increase the number of the Company’s authorized shares of common stock, $0.001 per value per share, from 200,000,000 shares to 500,000,000 shares (the “Amendment”). The Amendment was previously approved by the Company’s stockholders at the 2018 annual meeting of stockholders held on January 9, 2018.

 

On March 1, 2018, we filed a Certificate of Amendment to the Company’s Articles of Incorporation with the Secretary of State of Nevada to effect a 1-for-25 reverse stock split of all outstanding common stock shares of the Company (the “Amendment”). The reverse stock split was effective on March 5, 2018. The effect of the reverse stock split was to combine each 25 shares of outstanding common stock into one new share, with no change in authorized shares or par value per share, and to reduce the number of common stock shares outstanding from approximately 103.5 million shares to approximately 4.1 million shares (prior to rounding). Proportional adjustments were made to the conversion and exercise prices of the Company’s outstanding convertible preferred stock, warrants and stock options, and to the number of shares issued and issuable under the Company’s stock incentive plans. The reverse stock split did not affect any shareholder’s ownership percentage of the Company’s common stock, except to the limited extent that the reverse stock split resulted in any shareholder owning a fractional share. Fractional shares of common stock were rounded up to the nearest whole share based on each holder’s aggregate ownership of the Company. All issued and outstanding shares of common stock, conversion terms of preferred stock, options and warrants to purchase common stock and per share amounts contained in the financial statements, in accordance with SAB TOPIC 4C, have been retroactively adjusted to reflect the reverse split for all periods presented.

 

NOTE 2 – LIQUIDITY AND GOING CONCERN CONSIDERATIONS

 

At March 31, 2018, the Company’s total current liabilities of $40 million exceeded its total current assets of approximately $1.7 million, resulting in a working capital deficit of $38.3 million, while at March 31, 2017, the Company’s total current liabilities of $48.2 million exceeded its total current assets of $3.9 million, resulting in a working capital deficit of $44.3 million. The $6 million decrease in the working capital deficit is primarily the result of the settlement of the debt related to the Rogers Loan default and foreclosure (see below).

 

On December 30, 2015, the Company entered into an Asset Purchase Agreement (as amended from time to time, the “Asset Purchase Agreement”) to acquire, from twenty-three different entities and individuals (the “Sellers”), working interests in producing properties and undeveloped acreage (the “Acquisition”), which acquisition transaction was completed on August 25, 2016. The assets acquired include varied interests in two largely contiguous acreage blocks in the liquids-rich Mid-Continent region. In connection with the closing of the acquisition, we assumed approximately $30.6 million of commercial bank debt, issued 520,387 shares of common stock to certain of the Sellers, issued 552,000 shares of Series B Preferred Stock to one of the Sellers and its affiliate, and paid $4,975,000 in cash to certain of the Sellers. The effective date of the Acquisition was April 1, 2016.

 

Pursuant to a Letter Agreement we entered into, at the closing of the Acquisition, with RAD2, one of the Sellers, which is owned and controlled by Richard N. Azar II, our prior Chief Executive Officer and prior director. RAD2 agreed to accept full financial liability for any and all deficiencies between the “Agreed Assets Value” set forth in the Asset Purchase Agreement of $80,697,710, and the mutually agreed upon value of the assets delivered by the Sellers at the closing of the Acquisition, up to an aggregate of $1,030,941 (as applicable, the “Deficiency”). The Company accepted additional oil and gas producing properties and two salt water disposal facilities from the Sellers with an approximate value of $1.0 million to resolve this Deficiency.

 

The Asset Purchase Agreement between the Sellers and the Company relating to the Acquisition included the requirement that, following the closing, the parties undertake an accounting/true-up of expenses attributable to the assets acquired by the Company and revenue generated from such assets. A dispute arose between the Sellers and the Company as to the time period which the Company was to be responsible for the payment of expenses and was to receive the revenue from such assets prior to the closing of the transaction. Specifically, the Company believed that the agreements provided for it to be responsible for all expenses associated with the assets, and to receive all revenue generated from the assets, from April 1, 2016, the effective date of the Asset Purchase Agreement, through the closing date, August 25, 2016. The Sellers on the other hand, which include entities owned by Richard N. Azar, II, the Company’s then interim Chief Executive Officer, argued that the Company was only responsible for expenses, and was only due to receive revenue from the assets, beginning on the closing date, August 25, 2016. The difference in the amounts claimed due to the Company from the parties currently varied from a high of $1,121,718, which the Company alleged it is due, to a low of $342,298, which the Sellers alleged that the Company is due.

 

 F-6 
 

 

As discussed in “Note 6 – Notes Payable and Debenture”, the Company borrowed $40 million from IBC effective August 25, 2016. The proceeds of the loan were used to repay and refinance approximately $30.6 million of indebtedness owed by certain of the Sellers to IBC as part of the closing of the Acquisition. As of March 31, 2018, the Company was not in compliance with certain covenants of the loan agreement, including requiring the Company to maintain a net worth of $30 million, the Company is in default of the terms of the loan, and the balance of the loan due to IBC of $36.9 million (less unamortized debt issuance costs of approximately $1.3 million), was recognized as a short-term liability on the Company’s balance sheet as of March 31, 2018. The Company also recognized approximately $39,000 in accrued interest as of March 31, 2018 related to this note.

 

On April 6, 2016, the Company entered into a Securities Purchase Agreement (the “Securities Purchase Agreement”) with an accredited institutional investor (the “Investor”), pursuant to which we sold and issued a redeemable convertible subordinated debenture, with a face amount of $530,000, initially convertible into 6,523 shares of common stock (subject to certain conversion premiums) at a conversion price equal to $81.25 per share and a warrant to initially purchase 55,385 shares of common stock (subject to adjustment thereunder) at an exercise price equal to $81.25 per share (the “First Warrant”). The Investor purchased the debenture at a 5.0% original issue discount in the amount of $500,000 and has exercised the First Warrant in full as described below for the sum of $4.5 million.

 

Also on April 6, 2016, the Company entered into a Stock Purchase Agreement with the Investor, pursuant to which we agreed, subject to certain conditions, to issue up to 527 shares of Series C redeemable convertible preferred stock (the “Series C Preferred Stock”) at a 5% original issue discount, convertible into 64,738 shares of common stock (subject to certain conversion premiums) at a conversion price of $81.25 per share, and a warrant to initially purchase 44,444 shares of common stock at an exercise price of $112.50 per share (the “Second Warrant”). Under the terms of the Stock Purchase Agreement, the Second Warrant and 53 shares of Series C Preferred Stock were sold and issued for $500,000 on September 2, 2016, and the remaining 474 shares of Series C Preferred Stock were sold and issued for $4.5 million on November 17, 2016.

 

In July and August 2016, RAD2 advanced the Company an aggregate of $350,000. Also, in August 2016, two other Sellers advanced the Company an aggregate of $200,000 ($100,000 each). These advances did not accrue interest and had no stated maturity date. Additionally, in August 2016, RAD2 loaned us $1.5 million pursuant to a promissory note. The promissory note did not accrue interest for the first month it was outstanding and accrued interest at the rate of 5% per annum thereafter until paid in full. The Company repaid the promissory note in full and all amounts advanced by RAD2 and the two other Sellers in October 2016.

 

On October 7, 2016, the Investor exercised the First Warrant in full and was due 55,385 shares of common stock upon exercise thereof and an additional 101,709 shares of common stock in consideration for the conversion premium due thereon. A total of 32,400 shares were issued to the Investor on October 7, 2016, with the remaining shares being held in abeyance until such time as it would not result in the Investor exceeding its beneficial ownership limitation (4.99% of the Company’s outstanding common stock). The Company received gross proceeds of $4,500,000 from the exercise of the First Warrant and paid placement agent fees of $427,500 for services rendered in connection with the First Warrant. Pursuant to the terms of the First Warrant, the number of shares due in consideration for the conversion premium increases as the annual rate of return under the First Warrant increases, including by 10% upon the occurrence of certain triggering events (which had occurred by the October 7, 2016 date of exercise), to 17% per annum upon the exercise of the First Warrant. Additionally, as the conversion rate for the conversion premium is currently 85% of the lowest daily volume weighted average price during the measuring period, less $0.10 per share of common stock not to exceed 85% of the lowest sales prices on the last day of such period less $0.10 per share, the number of shares issuable in connection with the conversion premium increases as the trading price of our common stock decreases, and the trading price of our common stock has decreased since the date the First Warrant was exercised, triggering a further reduction in the conversion price of the conversion premium and an increase in the number of shares due to the Investor in connection with the conversion of the amount owed in connection with the conversion premium. Additionally, pursuant to the interpretation of the Investor, the measurement period for the calculation of the lowest daily volume weighted average price currently continues indefinitely.

 

 F-7 
 

 

On August 13, 2013, the Company entered into a $7.5 million Letter Loan Agreement with Louise H. Rogers (“Rogers” and such loan, as amended from time to time, the “Rogers Loan”). As a result of various extensions and amendments thereto the Rogers Loan was due and payable on July 31, 2017. The loan was not paid when due and the cure period on the Rogers Loan expired on September 11, 2017. On such date, all principal, interest and unpaid costs thereunder were immediately due and payable (which totaled approximately $9.4 million as of the date of acceleration which amount included $2.1 million of default interest). Prior to the default, CATI Operating, LLC (“CATI”), the Company’s wholly-owned subsidiary and obligor under the loan, had not recorded interest due on the note based on its earlier agreements. As a result of the default, demand and acceleration, CATI recorded the default interest demand of $2.1 million in the three month period ended December 31, 2017. In September 2017, Rogers foreclosed on the assets of CATI which secured the note. On October 3, 2017, the trustee of those assets, for the benefit of the lender, sold these assets in public auction foreclosure sales which took place in Gonzales County and Karnes County, Texas. The proceeds from the foreclosure sales of approximately $3.5 million were applied against the outstanding indebtedness.

 

On December 15, 2017, CATI entered into a Release of Mortgage, Deed of Trust, Assignment, Security Agreement, Financing Statement and Fixture Filing (the “Release”) with Rogers. Pursuant to the Release, the Company completed a transaction in which CATI provided Rogers, pursuant to an Assignment of Overriding Royalty Interest (the “Royalty Assignment”), with an overriding royalty (equal to 0.01 of 8/8ths of all oil and gas) on CATI’s remaining leasehold and Rogers released CATI from all remaining indebtedness owed. The Release, which was filed in various counties in Texas on January 22, 2018 and January 23, 2018, discharged approximately $5.8 million in principal and interest outstanding and owed to Rogers, according to Rogers. The effective date of the Release was December 15, 2017. Additionally, the remaining leasehold and ownership of CATI was assigned to Arkose Lease Partners, LLC, a third party (“Arkose”), pursuant to an Assignment of Membership Interest (the “Assignment”), dated November 1, 2017, in exchange for Arkose’s assumption of all plugging and abandonment liabilities of CATI of approximately $1.8 million.

 

Effective January 31, 2017, the Company borrowed $1,000,000 from Alan Dreeben, then one of the Company’s directors, pursuant to a short-term promissory note. The short-term promissory note had a principal balance of $1,050,000 (the $1,000,000 principal amount borrowed plus a $50,000 original issue discount), accrues interest at 6% per annum and a maturity date of January 31, 2018, with standard and customary events of default. As additional consideration for Mr. Dreeben agreeing to make the loan, we agreed to issue Mr. Dreeben 1,600 shares of restricted common stock. On November 9, 2017, in connection with the sale of the Jackrabbit Acreage, the Company repaid Mr. Dreeben the full amount due on the short-term promissory note of $1,050,000. See Note 4 “Property and Equipment” for further details.

 

On March 9, 2017, the Company borrowed $250,000 from a non-related individual pursuant to a short-term promissory note. The short-term promissory note has a principal balance of $263,158 (the $250,000 principal amount borrowed plus a $13,158 original issue discount), accrues interest at 6% per annum and has a maturity date of March 9, 2018 and contains standard and customary events of default. As additional consideration for agreeing to make the loan, we agreed to issue the lender 400 restricted shares of common stock. On November 9, 2017, in connection with the sale of the Jackrabbit Acreage, the Company paid the non-related individual the full amount due on the short-term promissory note of $263,158. See Note 4 “Property and Equipment” for further details.

 

On August 2, 2017, and effective June 13, 2017, the Company entered into an agreement with Vantage Fund, LLC (“Vantage” and the “Vantage Agreement”), pursuant to which Vantage agreed to provide up to $6 million of funding to the Company, in the sole discretion of Vantage, with $400,000 provided in the initial tranche (the “Initial Tranche”). The consideration for the Initial Tranche of funding was the assignment to Vantage of all of the Company’s rights and ownership in its then wholly-owned subsidiary Camber Permian II, LLC (“Camber Permian”), which included leaseholds and potential participation rights in undeveloped oil and gas property known as Arrowhead. The Vantage Agreement contained customary indemnification requirements. On July 17, 2017, Vantage provided $120,000 to the Company under the Vantage Note and on July 20, 2017, Vantage provided $30,000 to the Company under the Vantage Note. Vantage was granted a second lien on the Jackrabbit property in connection with the financing. On November 9, 2017, in connection with the sale of the Jackrabbit Acreage, the Company paid Vantage the full amount due on the Vantage Note of $150,000.

 

In addition to the transactions noted above, the Company is currently discussing potential financing transactions in order to fulfill our current capital requirements as well as our planned asset acquisition, which we believe, if finalized and completed, will ensure the future viability of the Company. However, due to our current capital structure and the nature of oil and gas interests, i.e., that rates of production generally decline over time as oil and gas reserves are depleted, if the Company is unable to obtain the necessary financing to finalize the asset purchase or drill additional wells and develop its proved undeveloped reserves (“PUDs”); coupled with the continued substantial drop in commodity prices over the last twelve months, the Company believe that its revenues will continue to decline over time. Therefore, the Company may be forced to scale back our business plan, sell assets to satisfy outstanding debts or take other remedial steps which may include seeking bankruptcy protection.

 

These conditions raise substantial doubt about the Company’s ability to continue as a going concern for the next twelve months following the issuance of these financial statements. The accompanying financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America on a going concern basis, which contemplates the realization of assets and the satisfaction of liabilities in the normal course of business. Accordingly, the financial statements do not include any adjustments relating to the recoverability of assets and classification of liabilities that might be necessary should the Company be unable to continue as a going concern.

 

 F-8 
 

 

 

NOTE 3 – SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

 

Principles of Consolidation

 

The financial statements of Camber Energy include the accounts of its wholly-owned subsidiaries, CATI Operating, LLC, a Texas limited liability company (“CATI”), CEI Operating LLC, a Texas limited liability company, Camber Permian LLC, a Texas limited liability company, Camber Permian II LLC, a Texas limited liability company, which was wholly-owned until it was divested on November 9, 2017, and CE Operating, LLC, an Oklahoma limited liability company. Per an amendment to the Rogers Loan, dated December 14, 2015, we transferred all of our oil and gas interests and equipment to CATI (see “Note 6 – Notes Payable” below). All intercompany accounts and transactions have been eliminated.

 

Use of Estimates

 

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America 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.

 

Camber’s financial statements are based on a number of significant estimates, including oil and natural gas reserve quantities which are the basis for the calculation of depreciation, depletion and impairment of oil and natural gas properties, and timing and costs associated with its asset retirement obligations, as well as those related to the fair value of stock options, stock warrants and stock issued for services. While we believe that our estimates and assumptions used in preparation of the financial statements are appropriate, actual results could differ from those estimates.

 

Cash and Cash Equivalents

 

Cash and cash equivalents include cash in banks and financial instruments which mature within three months of the date of purchase. The Company maintains cash and cash equivalents in bank deposit accounts, which at times may exceed federally insured limits of $250,000. At March 31, 2018 and 2017, the Company’s cash in excess of the federally insured limit were $490,460 and $199,435, respectively. Historically, the Company has not experienced any losses in such accounts. The Company had no cash equivalents at March 31, 2018 or 2017.

 

Accounts Receivable

 

Accounts receivable consist of uncollateralized oil and natural gas revenues due under normal trade terms. Management reviews receivables periodically and reduces the carrying amount by a valuation allowance that reflects management’s best estimate of the amount that may not be collectible. At March 31, 2018 and 2017, the Company’s allowance for doubtful accounts was $1,038,015 and $779,421, respectively.

 

Concentration of Credit Risk

 

The Company generally sells a significant portion of its oil and gas production to a relatively small number of customers. For the year ended March 31, 2018, the Company's consolidated revenues were from the sale of oil, gas and natural gas liquids under marketing contracts primarily with Superior Pipeline Company and Scissortail Energy, LLC. The Company is not dependent upon any one purchaser and have alternative purchasers available at competitive market prices if there is disruption in services or other events that cause the Company to search for other ways to sell our production.

 

During the year ended March 31, 2018, two customers accounted for 72.3% of the Company’s total revenues and during the year ended March 31, 2017, no one customer accounted for more than 20% of its total revenues. The Company does not believe the loss of any customer will have a material effect on the Company because alternative customers are readily available.

 

Oil and Natural Gas Properties, Full Cost Method

 

Camber uses the full cost method of accounting for oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and equip exploratory wells used to find proved reserves, and to drill and equip development wells including directly related overhead costs and related asset retirement costs are capitalized.

 

Under this method, all costs, including internal costs directly related to acquisition, exploration and development activities are capitalized as oil and natural gas property costs on a country-by-country basis. Costs not subject to amortization consist of unproved properties that are evaluated on a property-by-property basis. Amortization of these unproved property costs begins when the properties become proved or their values become impaired. Camber assesses overall values of unproved properties, if any, on at least an annual basis or when there has been an indication that impairment in value may have occurred. Impairment of unproved properties is assessed based on management’s intention with regard to future development of individually significant properties and the ability of Camber to obtain funds to finance their programs. If the results of an assessment indicate that the properties are impaired, the amount of the impairment is added to the capitalized costs to be amortized.

 

 F-9 
 

 

Sales of oil and natural gas properties are accounted for as adjustments to the net full cost pool with no gain or loss recognized, unless the adjustment would significantly alter the relationship between capitalized costs and proved reserves. If it is determined that the relationship is significantly altered, the corresponding gain or loss will be recognized in the statements of operations.

 

Costs of oil and natural gas properties are amortized using the units of production method. Amortization expense calculated per equivalent physical unit of production amounted to $5.74 and $10.98 per barrel of oil equivalent for the years ended March 31, 2018 and 2017, respectively.

 

Ceiling Test

 

In applying the full cost method, Camber performs an impairment test (ceiling test) at each reporting date, whereby the carrying value of property and equipment is compared to the “estimated present value” of its proved reserves discounted at a 10% interest rate of future net revenues, based on current economic and operating conditions at the end of the period, plus the cost of properties not being amortized, plus the lower of cost or fair market value of unproved properties included in costs being amortized, less the income tax effects related to book and tax basis differences of the properties. If capitalized costs exceed this limit, the excess is charged as an impairment expense.

 

During the year ended March 31, 2018, the Company recorded impairments totaling $8.1 million that were primarily related to unproved properties due to expirations of leaseholds. During the year ended March 31, 2017, the Company recorded impairments totaling $79.1 million, which represented $10.9 million related to proved properties, $18.7 million related to unproved properties, and $49.5 million in conjunction with the Acquisition, primarily due to continued low commodity prices during the fiscal year.

 

Asset Retirement Obligations

 

The Company records the fair value of a liability for asset retirement obligations (“ARO”) in the period in which it is incurred and a corresponding increase in the carrying amount of the related long-lived asset. The present value of the estimated asset retirement cost is capitalized as part of the carrying amount of the long-lived asset and is depreciated over the useful life of the asset. Camber accrues an abandonment liability associated with its oil and natural gas wells when those assets are placed in service. The ARO is recorded at its estimated fair value and accretion is recognized over time as the discounted liability is accreted to its expected settlement value. Fair value is determined by using the expected future cash outflows discounted at Camber’s credit-adjusted risk-free interest rate. No market risk premium has been included in Camber’s calculation of the ARO balance.

 

Other Property and Equipment

 

Other property and equipment are stated at cost and consist primarily of furniture and computer equipment. Depreciation is computed on a straight-line basis over the estimated useful lives.

 

Income Taxes

 

Deferred income taxes are provided on the liability method whereby deferred tax assets are recognized for deductible temporary differences and operating losses and tax credit carry-forwards and deferred tax liabilities are recognized for taxable temporary differences. Temporary differences are the differences between the reported amounts of assets and liabilities and their tax bases. 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 accrued tax liabilities are adjusted for the effects of changes in tax laws and rates on the date of enactment.

 

Camber has evaluated and concluded that there are no significant uncertain tax positions requiring recognition in the Company’s financial statements as of March 31, 2018 and 2017. The Company’s policy is to classify assessments, if any, for tax related interest expense and penalties as interest expense.

 

 F-10 
 

 

Earnings per Common Share

 

Basic and diluted net income per share calculations are calculated on the basis of the weighted average number of shares of the Company’s common stock outstanding during the year. Purchases of treasury stock reduce the outstanding shares commencing on the date that the stock is purchased. Common stock equivalents are excluded from the calculation when a loss is incurred as their effect would be anti-dilutive.

 

Stock options to purchase 78 shares of common stock at an average exercise price of $1,293.75 per share and warrants to purchase 72,608 shares of common stock at an average exercise price of $18.15 per share were outstanding at March 31, 2018. Stock options to purchase 798 shares of common stock at a weighted average exercise price of $885.23 per share and warrants to purchase 10,261 shares of common stock at a weighted average exercise price of $321.01 per share were outstanding at March 31, 2017.

 

Using the treasury stock method, had the Company had net income, no common shares attributable to our outstanding stock options would have been included in the fully diluted earnings per share calculation for the years ended March 31, 2018 and 2017.

 

Fair Value of Financial Instruments

 

ASC 820 defines fair value, establishes a framework for measuring fair value and enhances disclosures about fair value measurements. It defines fair value as the exchange price that would be received for an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. ASC 820 also establishes a fair value hierarchy which requires an entity to maximize the use of observable inputs and minimize the use of unobservable inputs when measuring fair value. The standard describes three levels of inputs that may be used to measure fair value:

 

Level 1 – Quoted prices in active markets for identical assets or liabilities.
Level 2 – Inputs other than quoted prices that are observable for the asset or liability, either directly or indirectly. These include quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities that are not active; and model-driven valuations whose inputs are observable or whose significant value drivers are observable. Valuations may be obtained from, or corroborated by, third-party pricing services.
Level 3 – Unobservable inputs to measure fair value of assets and liabilities for which there is little, if any market activity at the measurement date, using reasonable inputs and assumptions based upon the best information at the time, to the extent that inputs are available without undue cost and effort.

 

As of March 31, 2018, the significant inputs to the Company’s derivative liability calculation were Level 3 inputs.

 

Share-Based Compensation

 

Camber measures the cost of employee services received in exchange for an award of equity instruments based on the grant-date fair value of the award over the vesting period.

 

Revenue and Cost Recognition

 

Camber recognizes oil and natural gas revenue under the sales method of accounting for its interests in producing wells as crude oil and natural gas is produced and sold from those wells. Costs associated with production are expensed in the period incurred. Crude oil produced but remaining as inventory in field tanks is not recorded as revenue in Camber’s financial statements because it is not material.

 

Reclassifications

 

Certain reclassifications have been made to the prior year financial statements to conform with the current year presentation.

 

 F-11 
 

 

Recently Issued Accounting Pronouncements

 

There were various accounting standards and interpretations issued during fiscal 2018 and 2017, none of which are expected to have a material impact on the Company’s financial position, operations or cash flows.

 

In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers (“ASU 2014-09”), which supersedes nearly all existing revenue recognition guidance under GAAP. The core principle of ASU 2014-09 is to recognize revenues when promised goods or services are transferred to customers in an amount that reflects the consideration to which an entity expects to be entitled for those goods or services. ASU 2014-09 defines a five-step process to achieve this core principle and, in doing so, more judgment and estimates may be required within the revenue recognition process than are required under existing GAAP. The guidance is effective for annual and interim periods beginning after December 15, 2017. The standard is required to be adopted using either the full retrospective approach, with all prior periods presented adjusted, or the modified retrospective approach, with a cumulative adjustment to retained earnings on the opening balance sheet. The Company will adopt the new standard utilizing the modified retrospective approach. The Company does not expect the adoption of this ASU to have a material impact on its financial statements. However, we anticipate the new standard will result in more robust footnote disclosures.

 

In August 2014, the FASB issued ASU 2014-15, Disclosure of Uncertainties about an Entity’s Ability to Continue as a Going Concern. The new standard requires management to assess the Company’s ability to continue as a going concern. Disclosures are required if there is substantial doubt as to the Company’s continuation as a going concern within one year after the issue date of financial statements. The standard provides guidance for making the assessment, including consideration of management’s plans which may alleviate doubt regarding the Company’s ability to continue as a going concern. ASU 2014-15 is effective for years ending after December 15, 2016. The Company adopted this standard for the year ending March 31, 2017, and management has concluded that there is substantial doubt as to the Company’s continuation as a going concern within one year after the issue date of the financial statements.

 

In February 2016, the FASB issued ASU 2016-02, a new lease standard requiring lessees to recognize lease assets and lease liabilities for most leases classified as operating leases under previous U.S. GAAP. The guidance is effective for fiscal years beginning after December 15, 2018, with early adoption permitted. The Company will be required to use a modified retrospective approach for leases that exist or are entered into after the beginning of the earliest comparative period in the financial statements. The Company is currently evaluating the impact of adopting this standard on its consolidated financial statements.

 

In August 2016, the FASB issued Accounting Standards Update (ASU) 2016-15, Statement of Cash Flows (Topic 230). ASU 2016-15 seeks to reduce the existing diversity in practice in how certain cash receipts and cash payments are presented and classified in the statement of cash flows. This update is effective for fiscal years beginning after December 15, 2017, including interim periods within those fiscal years, with early adoption permitted. The Company is currently evaluating the provisions of ASU 2016-15 and assessing the impact, if any, it may have on its statement of consolidated cash flows.

 

In January 2017, the Financial Accounting Standards Board (“FASB”) issued Accounting Standard Update (“ASU”) 2017-01, Business Combinations: Clarifying the Definition of a Business, which amends the current definition of a business. Under ASU 2017-01, to be considered a business, an acquisition would have to include an input and a substantive process that together significantly contributes to the ability to create outputs. ASU 2017-01 further states that when substantially all of the fair value of gross assets acquired is concentrated in a single asset (or a group of similar assets), the assets acquired would not represent a business. The new guidance also narrows the definition of the term “outputs” to be consistent with how it is described in Topic 606, Revenue from Contracts with Customers. The changes to the definition of a business will likely result in more acquisitions being accounted for as asset acquisitions. The guidance is effective for the annual period beginning after December 15, 2017, with early adoption permitted. The Company is currently evaluating the effects of ASU 2017-01.

 

In May 2017, the FASB issued ASU 2017-09, “Compensation-Stock Compensation (Topic 718): Scope of Modification Accounting”, which provides guidance about which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting in Topic 718. ASU 2017-09 is effective for annual periods beginning after December 15, 2017, with early adoption permitted, including adoption in any interim period for which financial statements have not yet been issued. The Company is currently evaluating the impact of adopting this standard on its consolidated financial statements.

 F-12 
 

 

NOTE 4 – PROPERTY AND EQUIPMENT

 

Oil and Natural Gas Properties

 

All of Camber’s oil and natural gas properties are located in the United States. Costs being amortized at March 31, 2018 and 2017 are as follows:

 

  At March 31,
  2018  2017
 Oil and gas properties subject to amortization  $60,760,056   $72,318,163 
 Oil and gas properties not  subject to amortization   28,016,989    28,947,400 
 Capitalized asset retirement costs   322,470    1,473,199 
 Total oil & natural gas properties   89,099,515    102,738,762 
 Accumulated depreciation, depletion, and impairment   (76,555,320)   (67,036,915)
 Net Capitalized Costs  $12,544,195   $35,701,847 

 

Impairment

During the year ended March 31, 2018, the Company recorded impairments totaling $8.1 million that were primarily related to unproved properties due to expirations of leaseholds. During the year ended March 31, 2017, the Company recorded impairments totaling $79.1 million, which represented $10.9 million related to proved properties, $18.7 million related to unproved properties, and $49.5 million in conjunction with the Acquisition, primarily due to continued low commodity prices during the fiscal year.

 

Disposition of Oil and Natural Gas Properties

On August 2, 2017, the Company entered into an agreement with Vantage pursuant to which Vantage agreed to provide up to $6 million of funding to the Company, at the sole discretion of Vantage. On June 12, 2017, the Company received the initial tranche of $400,000. In exchange for the cash received, the Company assigned its interest in the undeveloped Arrowhead oil and gas property, with a book value of $114,500, to Vantage and granted warrants to purchase 64,000 shares of the Company's common stock (see further discussion of these warrants in Note 10). The Company recorded a gain of $1,195 as a result of this assignment that was recorded in loss on sale of property and equipment for the year ended March 31, 2018.

On June 12, 2017, the Company received the initial tranche of $400,000 in connection with the Vantage Agreement. In exchange for the cash received, the Company assigned its interest held in Camber Permian in the undeveloped Arrowhead oil and gas property, with a book value of $114,500, to Vantage and granted warrants to purchase 64,000 shares of the Company’s common stock (see further discussion of these warrants in Note 10). The Company recorded a gain of $1,195 as a result of this assignment that was recorded in loss on sale of property and equipment as of March 31, 2018.

The cure period on the Rogers Loan expired on September 11, 2017, and as of such date, all principal, interest and unpaid costs thereunder were immediately due and payable (which totaled approximately $9.4 million as of the date of acceleration which amount included $2.1 million of default interest). Prior to the default, CATI had not recorded interest due on the note based on its earlier agreements. As a result of the default, demand and acceleration, CATI recorded the default interest demand of $2.1 million in the three-month period ended December 31, 2017. In September 2017, Rogers foreclosed on the assets of CATI which secured the note. On October 3, 2017, the trustee of those assets, for the benefit of the lender, sold these assets in public auction foreclosure sales which took place in Gonzales County and Karnes County, Texas. The proceeds from the foreclosure sales of approximately $3.5 million were applied against the outstanding indebtedness. The Company recorded an approximate loss on sale of property of approximately $4.1 million in conjunction with the settlement of the approximate $9.4 million of debt and accrued interest and the removal of approximately $1.3 million of remaining ARO.

On December 15, 2017, CATI entered into a Release of Mortgage, Deed of Trust, Assignment, Security Agreement, Financing Statement and Fixture Filing (the “Release”) with Rogers. Pursuant to the Release, the Company completed a transaction in which CATI provided Rogers, pursuant to an Assignment of Overriding Royalty Interest (the “Royalty Assignment”), with an overriding royalty (equal to 0.01 of 8/8ths of all oil and gas) on CATI’s remaining leasehold and Rogers released CATI from all remaining indebtedness owed. The Release, which was filed in various counties in Texas on January 22, 2018 and January 23, 2018, discharged approximately $5.8 million in principal and interest outstanding and owed to Rogers, according to Rogers. The effective date of the Release was December 15, 2017. Additionally, the remaining leasehold and ownership of CATI was assigned to Arkose Lease Partners, LLC, a third party (“Arkose”), pursuant to an Assignment of Membership Interest (the “Assignment”), dated November 1, 2017, in exchange for Arkose’s assumption of all plugging and abandonment liabilities of CATI. See Note 6 “Notes Payable and Debenture” for further details.

Effective November 1, 2017, the Company and NFP Energy LLC (“NFP”) its joint venture partner, sold its 90% ownership position in oil and gas properties totaling approximately 2,452 acres in Gaines County, Texas, to Fortuna Resources Permian (“Fortuna”), for $1,000 per acre or an aggregate of $2,206,718 payable to the Company. The Company paid NFP $662,072 to terminate the joint venture agreement and the property sold had a net book value of $817,110. The transaction resulted in a $727,732 gain which is included in Loss on Sale of Property and Equipment on the statement of operations. This acreage, part of the Company’s “Jackrabbit” acreage, targeted the San Andres formation in the Permian Basin.  Additionally, the Company and NFP jointly terminated their venture.  With the proceeds from the sale, the Company paid the first lien holders including Alan Dreeben (a former director of the Company) and second lien holder Vantage. The Company maintains a 90% ownership position in the remaining approximately 1,200 acres in the area.

 F-13 
 

 

Acquisition of Oil and Natural Gas Properties

On August 25, 2016, the Company completed the Acquisition and acquired working interests in producing properties and undeveloped acreage from the Sellers (see “Note 2 – Liquidity and Going Concern Considerations”). The assets acquired include varied interests in two largely contiguous acreage blocks in the liquids-rich Mid-Continent region.

 

As consideration for the Acquisition of the acquired assets, the Company assumed approximately $30.6 million of commercial bank debt, issued 520,387 shares of common stock to certain of the Sellers valued at the grant date fair value, issued 552,000 shares of Series B Preferred Stock to one of the Sellers and its affiliate (see “Note 7 – Stockholders’ Equity”) valued at the grant date fair value, and paid $4,975,000 in cash to certain of the Sellers. The effective date of the Acquisition was April 1, 2016.

 

The following tables summarize the purchase price and allocation of the purchase price to the net assets acquired in connection with the Acquisition:

 

Purchase Price on August 25, 2016:  Consideration Given
Fair value of common stock issued  $49,176,530 
Fair value of Series B Preferred Stock issued   14,898,038 
Assumption of debt   30,595,256 
Cash paid at closing   4,975,000 
Total purchase price  $99,644,824 
      
    Net Assets Acquired 
Accounts receivable  $635,482 
Total current assets acquired   635,482 
      
Oil and gas properties   50,774,684 
Total assets acquired   51,410,166 
      
Asset retirement obligations   (755,862)
Total liabilities acquired   (755,862)
      
Net assets acquired   50,654,304 
      
Impairment of oil and gas properties   48,990,520 
      
Total Purchase Price  $99,644,824 

 

The proceeds from the $40 million loan from IBC were as follows:

 

   Use of Proceeds
Assumption of debt  $30,595,256 
Cash funding (paid at closing)   4,975,000 
Loan Commitment fee (paid at closing)   200,000 
Lien Payoff (paid at closing)   72,657 
Restricted cash (received at closing)   3,360,000 
Cash (received at closing)   797,087 
Debt payable after closing  $40,000,000 

  

In January 2018, the Company acquired approximately 3,000 leasehold acres in Okfuskee County, Oklahoma, including two producing wells and 7 non-producing well bores, in consideration for cash paid of $210,000. The acquisition included three salt water disposal wells, to support existing and potential future hydrocarbon production.

 

 F-14 
 

 

In March 2018, the Company completed an acquisition of working interest in certain leases, wells and equipment located in the Texas panhandle, for a purchase price of $250,000, payable in three tranches. A payment of $85,000 was due at closing; $85,000 was due thirty days after closing and $80,000 was due sixty days after closing these remaining payments have been accrued as of March 31, 2018 and are included in accrued expenses on the balance sheet. Camber earned 25% of the working interest at the closing and earned an additional 25% of the working interest at each of the two subsequent closings. The seller retained a 25% carried working interest in the assets. The acquisition includes 49 non-producing well bores, 5 saltwater disposal wells and the required infrastructure and equipment necessary to support future hydrocarbon production, as well as approximately 500 net leasehold acres in Hutchinson County, Texas.

 

Capital Leases

 

In March 2018, the Company purchased certain equipment pursuant to capital leases. The effective value of the equipment was approximately $278,000 and such amount is included in Oil and Gas Properties and the corresponding liability of approximately $278,000 is included in Accrued Expenses. The effective borrowing rate is approximately 35% and all obligations are due by December 2018.

 

Other Property and Equipment

 

In February 2014, the Company purchased a field office for approximately $50,000 which is used to provide local operational support for its properties in the Eagleford and Austin Chalk areas. The land upon which the field office resides was initially leased by the Company over a three-year term beginning in January 2014 through December 2016, for a yearly lease amounts of $7,200 and $7,800, and $8,400 over the three-year term, respectively. In January 2017, the Company renewed the lease on a year-to-year basis for $7,200. The field office was transferred as a part of the Release with Rogers. See Note 6 “Notes Payable and Debenture” for further details.

Office Lease

 

On April 1, 2016, the Company entered into a lease agreement pursuant to which the Company agreed to lease 4,439 square feet of office space at 450 Gears Road, Houston, Harris County, Texas 77067 (Suite 860, versus Suite 780 as was leased previously). The lease had a 65-month term (through August 2021), and commenced on April 1, 2016. The monthly rental cost under the lease was -$0- for the month of April 2016, and $7,676 for the months of May 2016 through April 2017, plus as applicable, its pro rata share of operating expenses and taxes which exceed the total operating expenses and taxes of the property for the first year of the lease. On March 31, 2017, the Company amended its lease at 450 Gears Road to expand to a total of 6,839 square feet, commencing on May 1, 2017. The amendment extended the lease period to November 2021.

 

In August 2017, the Company ceased its use of this office space and moved its headquarters to San Antonio, Texas. The Company is committed to the remaining lease payments for the Houston office space for approximately $346,000 assuming an early termination of the lease on July 31, 2019. The Company recorded monthly rent expense associated with the Houston lease through August 2017. In accordance with the accounting guidance in ASC 420-10-25-13 regarding exit or disposal cost obligations, as of August 2017, the Company recorded rent expense, within general and administrative expense, and accrued a liability of $302,289, which represents the fair value of costs that will continue to be incurred during the remaining term of the Houston lease without economic benefit to the Company. As of March 31, 2018, the remaining carrying amount of the liability of $226,972 was included in accrued expenses on the Company’s balance sheet. In addition, the Company wrote-off $189,533 of mostly fully depreciated property and equipment that was not re-located to the San Antonio headquarters resulting in a loss of $3,368 which was included in loss on sale of property and equipment on the income statement as of March 31, 2018.

 

Effective October 1, 2017, the Company entered into an agreement to sublease space on a month to month basis in San Antonio, Texas at 4040 Broadway, Suite 425 from RAD2 Minerals, Ltd., an entity owned and controlled by Mr. Azar, the Company’s former Interim Chief Executive Officer, who resigned as Interim CEO effective May 25, 2018 and resigned as a member of the Board of Directors on June 21, 2018. Monthly rent for October through December 2017 was $5,000 per month, increasing to $7,500 per month effective January 2018. The lease agreement was terminated effective June 30, 2018. The Company agreed under a verbal contract to lease the same space on a month-to-month basis for $2,500 per month beginning effective July 1, 2018.

 

NOTE 5 – ASSET RETIREMENT OBLIGATIONS

 

The following table presents the reconciliation of the beginning and ending aggregate carrying amounts of long-term legal obligations associated with the future retirement of oil and natural gas properties for the years ended March 31, 2018 and 2017:

 

 F-15 
 

 

 

   2018  2017
Carrying amount at beginning of year  $2,045,847   $1,179,170 
Acquisition of oil and gas properties   437,071    755,862 
Accretion   92,620    199,960 
Disposition due to Rogers foreclosure   (1,328,260)   —   
Revisions of previous estimates   (268,119)   (89,145)
Carrying amount at end of year  $979,159   $2,045,847 

 

NOTE 6 – NOTES PAYABLE AND DEBENTURE

The Company’s notes payable and debenture consisted of the following:

   March 31,  March 31,
   2018  2017
Note Payable - Rogers  $—     $6,883,697 
Note Payable - Dreeben   —      1,050,000 
Note Payable - Stewart   —      263,158 
Debenture   495,000    530,000 
Note Payable - IBC   36,943,617    38,324,527 
    37,438,617    47,051,382 
Unamortized debt discount   (1,499,647)   (2,624,038)
Total Notes Payable and Debenture   35,938,970    44,427,344 
Less current portion   (35,691,567)   (44,281,649)
Long-term portion  $247,403   $145,695 

 

Rogers Loan and Promissory Note

Letter Loan Agreement

 

At March 31, 2017, the Company had $6,883,697 due under the $7.5 million Letter Loan Agreement originally entered into with Rogers on August 13, 2013.

 

Additionally, per a prior amendment, the Company transferred all of its oil and gas interests and equipment to our then newly formed wholly-owned Texas subsidiary, CATI which clarified that following the transfer, Rogers had no right to foreclose upon the Company (at the Nevada corporate parent level) upon the occurrence of an event of default under the Rogers Loan, and that instead Rogers would only take action against CATI and its assets and required Rogers to release all UCC and other security filings on the Company (provided that Rogers is allowed to file the same filings on CATI and its assets). Subsequently, the Company assigned all of its oil and gas interests and equipment to CATI pursuant to an Assignment and Bill of Sale dated December 16, 2015.

 

On February 1, 2017, the Company agreed to extend the maturity date of the Rogers Loan from January 31, 2017 to April 30, 2017. As consideration, the Company paid $9,000 to Rogers and $9,000 to Robertson Global Credit, LLC (“Robertson”), the servicer of the loan. In April 2017, the maturity date was extended again until July 31, 2017. As consideration, the Company paid $9,000 to Ms. Rogers and $9,000 to Robertson. The Company failed to pay the amount due to Rogers on July 31, 2017.

 

On August 25, 2017, the Company received a notice that its wholly-owned subsidiary CATI had defaulted on the maturity payment of its loan with Rogers, which matured on July 31, 2017. The letter stated that CATI was indebted to Rogers in an amount of $8.9 million, which includes all principal and interest (of which $2.1 million was default interest) through August 25, 2017. The letter further asserted additional interest of $3,577 per day as well as other unpaid fees totaling $18,162 plus interest on those fees. The default notice further stated that the default in failing to pay the fees must be cured by September 5, 2017 and the default on the principal and interest payment must be cured by September 11, 2017.


 F-16 
 

 

The cure period on the Rogers Loan expired on September 11, 2017, and as of such date, all principal, interest and unpaid costs thereunder were immediately due and payable (which totaled approximately $9.4 million as of the date of acceleration which amount included $2.1 million of default interest). Prior to the default, CATI had not recorded interest due on the note based on its earlier agreements. As a result of the default, demand and acceleration, CATI recorded the default interest demand of $2.1 million in the three-month period ended December 31, 2017. In September 2017, Rogers foreclosed on the assets of CATI which secured the note. On October 3, 2017, the trustee of those assets, for the benefit of the lender, sold these assets in public auction foreclosure sales which took place in Gonzales County and Karnes County, Texas. The proceeds from the foreclosure sales of approximately $3.5 million were applied against the outstanding indebtedness. The Company recorded an approximate loss on sale of property of approximately $4.1 million in conjunction with the settlement of the approximate $9.4 million of debt and accrued interest and the removal of approximately $1.3 million of remaining ARO.

 

On December 15, 2017, CATI entered into a Release of Mortgage, Deed of Trust, Assignment, Security Agreement, Financing Statement and Fixture Filing (the “Release”) with Rogers. Pursuant to the Release, the Company completed a transaction in which CATI provided Rogers, pursuant to an Assignment of Overriding Royalty Interest (the “Royalty Assignment”), with an overriding royalty (equal to 0.01 of 8/8ths of all oil and gas) on CATI’s remaining leasehold and Rogers released CATI from all remaining indebtedness owed. The Release, which was filed in various counties in Texas on January 22, 2018 and January 23, 2018, discharged approximately $9.4 million in principal and interest outstanding and owed to Rogers, according to Rogers. The effective date of the Release was December 15, 2017. Additionally, the remaining leasehold and ownership of CATI was assigned to Arkose Lease Partners, LLC, a third party (“Arkose”), pursuant to an Assignment of Membership Interest (the “Assignment”), dated November 1, 2017, in exchange for Arkose’s assumption of all plugging and abandonment liabilities of CATI.

 

Promissory Note

 

On August 25, 2016, and effective on August 15, 2016, our wholly-owned subsidiary, CATI borrowed $1 million from the Company’s senior lender, Rogers. The amount borrowed accrued interest at the rate of 12% per annum (18% upon the occurrence of an event of default) and was due and payable on or before November 9, 2016. The note is secured by the assets of CATI and nine of our other assets, including those acquired in the Acquisition.

 

Pursuant to the terms of the note, a total of 80% of all cash flow generated by CATI was required to first be paid to satisfy amounts owed under the August 2016 Note, and then to amounts owed under the Letter Loan, with the remaining 20% of such cash flow used by CATI for lease and other operating expenses and capital expenditures approved by Rogers’ designated representatives. In connection with the Company’s entry into the August 2016 note, it paid a loan origination fee of $50,000 and agreed to pay all fees of Rogers’ counsel in connection with the preparation and negotiation of the note. The $50,000 loan origination fee was recorded as a debt discount and was amortized through interest expense using the effective interest method over the term of the note.

 

As additional consideration, CATI issued Robertson Global Credit, LLC, the administrator of the Rogers Loan, a 2% overriding royalty interest in the wellbores of the Cyclone #9H and Cyclone #10H wells.

 

On October 11, 2016, the Company paid Rogers the full amount of principal due on the promissory note of $1.0 million and also paid the full amount of interest due of $15,667 on October 13, 2016. As such, the promissory note was no longer outstanding as of March 31, 2017.

 

Silver Star Line of Credit

 

On August 30, 2015, the Company entered into a Non-Revolving Line of Credit Agreement with Silver Star Oil Company (“Silver Star”). The line of credit provided the Company the right to issue up to $2.4 million in convertible promissory notes to Silver Star. To date, Camber has drawn $1,000,000 under the line of credit for the months of October, November, December 2015 and January and February 2016. The convertible notes contained a beneficial conversion feature with a combined intrinsic value of $687,987 for the five notes, which was recognized as a debt discount and is being amortized through interest expense using the effective interest method over the term of the notes.

 

Convertible notes totaling $800,000 had been assigned by Silver Star to Rockwell Capital Partners (“Rockwell”), of which Rockwell has fully converted a total of $830,562 of the principal and interest due on such convertible notes outstanding into shares of our common stock at a conversion price of $37.50 per share, for an aggregate of 22,148 shares.

 

On July 15, 2016, pursuant to an assignment of convertible promissory note agreement, the Company was advised that the last $200,000 convertible promissory note issued to Silver Star on February 20, 2016 was assigned by Silver Star to Texas Capital & Assets LLC. On September 28, 2016, Texas Capital & Assets LLC converted $207,566 of principal and interest due on such convertible note into shares of our common stock at a conversion price of $37.50 per share, for an aggregate of 5,535 shares.

 

 F-17 
 

 

As of March 31, 2017, the Company had no remaining Silver Star convertible notes outstanding as all outstanding notes had been converted into shares of the Company’s common stock.

 

HFT Convertible Promissory Note Purchase Agreement and Convertible Promissory Notes

 

On March 29, 2016, Camber entered into a Convertible Promissory Note Purchase Agreement with HFT Enterprises, LLC (“HFT”). Pursuant to the Note Purchase Agreement, Camber agreed to sell an aggregate of $600,000 in convertible notes, including $450,000 in convertible notes purchased on the date of the parties’ entry into the agreement, and $150,000 in convertible notes purchased by Debra Herman, the wife of Michael Herman, the principal of HFT, on April 26, 2016. Camber also granted Mrs. Herman warrants to purchase 4,971 shares of common stock with an exercise price of $37.50 per share on April 26, 2016, when the final loan was made pursuant to the terms of the agreement. The fair value of these warrants of $470,467 and the relative fair value of $113,737 was recorded as additional debt discount.

 

Each of the convertible notes are due and payable twelve months from their issuance date, accrue interest at the rate of 6% per annum (15% upon the occurrence of an event of default), and allow the holder thereof the right to convert the principal and interest due thereunder into common stock of the Company at a conversion price of $37.50 per share, provided that the total number of shares of common stock issuable upon conversion of the convertible notes could not exceed 19.9% of our outstanding shares of common stock on March 29, 2016, until shareholder approval for such issuances was received, which approval was received on August 23, 2016. The convertible notes contained a beneficial conversion feature with a combined intrinsic value of $600,000 for the three notes, which is recognized as a discount and is being amortized through interest expense using the effective interest method over the term of the notes.

 

On October 4, 2016, HFT, converted $464,800 of the principal and interest due on such convertible notes held by HFT into shares of Camber common stock at a conversion price of $37.50 per share, for an aggregate of 12,395 shares. Additionally, on November 18, 2016, Mrs. Herman converted $155,110 of the principal and interest due on the convertible note which she held into shares of our common stock at a conversion price of $37.50 per share, for an aggregate of 4,136 shares.

 

As of March 31, 2018 and 2017, the Company had no remaining HFT convertible notes outstanding and does not recognize any corresponding liability on the Company’s balance sheet as all outstanding notes had been converted into shares of the Company’s common stock.

 

Dreeben Note

On March 28, 2016, the Company borrowed $250,000 from Alan Dreeben, one of the Sellers and one of the Company’s then directors, pursuant to a short-term promissory note. The short-term promissory note has a principal balance of $275,000 (the $250,000 borrowed plus a $25,000 original issue discount). As additional consideration for Mr. Dreeben agreeing to make the loan, the Company agreed to issue Mr. Dreeben 600 shares of restricted common stock, which were issued in September 2016. The Company recognized a $48,000 discount to the short-term promissory note which was based on the closing price of the Company’s common stock ($80.00 per share) on March 28, 2016 in addition to the original discount of $25,000, for a total discount of $73,000.

 

On June 27, 2016, the Company entered into an amended and restated short-term promissory note, amending and restating the note originally entered into with Mr. Dreeben on March 28, 2016; evidencing an additional $100,000 borrowed on June 13, 2016, plus a $10,000 original issue discount on such loan amount and extending the maturity date of the note to August 31, 2016.

 

On August 31, 2016, the Company paid Mr. Dreeben the full amount due on the short-term promissory note of $385,000.

 

Effective January 31, 2017, the Company borrowed $1,000,000 from Alan Dreeben, one of the Company’s then directors, pursuant to a short-term promissory note. The short-term promissory note had a principal balance of $1,050,000 (the $1,000,000 principal amount borrowed plus a $50,000 original issue discount), accrues interest at 6% per annum and a maturity date of January 31, 2018, with standard and customary events of default. As additional consideration for Mr. Dreeben agreeing to make the loan, we agreed to issue Mr. Dreeben 1,600 shares of restricted common stock. At March 31, 2017, the Company owed $1,050,000 to Alan Dreeben. The fair value of the restricted shares was $30,000 based on the closing price of the Company’s common stock on the issuance date. The fair value of the shares was recorded as additional debt discount. At March 31, 2017, the Company owed $1,050,000 to Alan Dreeben. The Company also recognized $10,500 in accrued interest as of March 31, 2017.

 F-18 
 

 

On November 9, 2017, in connection with the sale of the Jackrabbit Acreage, the Company repaid Mr. Dreeben the full amount due on the short-term promissory note of $1,050,000. See Note 4 “Property and Equipment” for further details.

 

Non-Related Individual Note

On March 9, 2017, the Company borrowed $250,000 from a non-related individual pursuant to a short-term promissory note. The short-term promissory note has a principal balance of $263,158 (the $250,000 principal amount borrowed plus a $13,158 original issue discount), accrues interest at 6% per annum and has a maturity date of March 9, 2018 and contains standard and customary events of default. As additional consideration for agreeing to make the loan, the Company agreed to issue the lender 400 restricted shares of common stock. The fair value of the restricted shares was $5,900 based on the closing price of the Company’s common stock on the issuance date. The fair value of the shares was recorded as additional debt discount. The note is secured by a deed of trust on certain of our properties. At March 31, 2017, the Company owed $263,158 to the non-related individual. The Company also recognized $1,316 in accrued interest as of March 31, 2017. On November 9, 2017, in connection with the sale of the Jackrabbit Acreage, the Company paid the non-related individual the full amount due on the short-term promissory note of $263,158. See Note 4 “Property and Equipment” for further details.

 

Debenture

 

On April 6, 2016, the Company entered into a Securities Purchase Agreement with the Investor, pursuant to which the Company issued a redeemable convertible subordinated debenture, with a face value of $530,000, initially convertible into 6,523 shares of common stock at a conversion price equal to $81.25 per share and warrants to initially purchase 55,385 shares of common stock (subject to adjustment thereunder) at an exercise price equal to $81.25 per share (the “First Warrant”). The Investor purchased the debenture at a $30,000 original issue discount for the sum of $500,000 and agreed that it would exercise the First Warrant, upon satisfaction of certain conditions, for the sum of $4.5 million, which warrant was exercised in October 2016. The debenture matures in seven years and accrues interest at a rate of 6.0% per annum. Due to the recent decline in the price of our common stock and that a trigger event occurred on June 30, 2016 as a result of the delay in filing our Annual Report on Form 10-K for the year ended March 31, 2016, the premium rate on the debenture increased from 6% to 34% and the conversion discount became 85% of the lowest daily volume weighted average price during the measuring period (60 days prior to and 60 days after the last date that the Investor receives the last of the shares due), less $0.10 per share of common stock not to exceed 85% of the lowest sales price on the last day of such period less $0.10 per share. On August 23, 2017, the Investor converted $35,000 of the principal amount of the Debenture into an aggregate of 70,189 shares of common stock, which included 431 shares for conversion of principal (at $81.25 per share) and 69,758 shares for premiums.

 

As the fair value of the warrants issued in connection with the debenture exceeds the $530,000 value of the debenture, we fully discounted the entire debenture and will amortize the discount over the term of the debenture. The discount is being amortized through interest expense using the effective interest method over the term of the debenture.

 

As of March 31, 2018 and 2017, the Company had a convertible subordinated debenture with a balance of $247,403 and $145,695, respectively (net of unamortized discount of $247,597 and $384,305, respectively) which is recognized as a long-term liability on the Company’s balance sheet as of March 31, 2018 and 2017. The Company also recognized $338,183 and $180,200 in accrued interest as of March 31, 2018 and 2017, respectively.

 

Loan Agreement with International Bank of Commerce (“IBC”)

 

On August 25, 2016, the Company, as borrower, and Richard N. Azar II, our former Chief Executive Officer and former director, and who also received the largest number of securities and cash in connection with the closing of the Acquisition (“Azar”), Donnie B. Seay, our current director, Richard E. Menchaca, RAD2, DBS Investments, Ltd. (“DBS”, controlled by Mr. Seay) and Saxum Energy, LLC (“Saxum”, which is controlled by Mr. Menchaca), as guarantors (collectively, the “Guarantors”, all of which were directly or indirectly Sellers), and IBC, as Lender (“Lender”), entered into a Loan Agreement.

 

Pursuant to the Loan Agreement, the Lender loaned the Company $40 million, evidenced by a Real Estate Lien Note in the amount of $40 million. The Company is required to make monthly payments under the note equal to the greater of (i) $425,000; and (ii) fifty percent (50%) of our monthly net income. The note accrues annual interest at 2% above the prime rate then in effect, subject to a minimum interest rate of 5.5% per annum. The note is due and payable on August 25, 2019. Payments under the note are subject to change as the interest rate changes in order to sufficiently amortize the note in 120 monthly installments. The Company has the right, from time to time and without penalty to prepay the note in whole or in part, subject to the terms thereof.

 

 F-19 
 

 

The proceeds of the loan were used to repay and refinance approximately $30.6 million of indebtedness owed by certain of the Sellers, to the Lender (including an aggregate of $18.3 million owed by RAD2 and another entity controlled by Mr. Azar, $9.8 million owed by DBS, and $2.1 million owed by Mr. Menchaca), as well as to pay the $4.975 million due to the Sellers at closing. Another $3.36 million was used to fund a sinking fund required by the Lender, as discussed below, to pay principal on the note.

 

The amount owed under the note is secured by a Security Interest in substantially all of our assets and properties, pursuant to three Security Agreements. Also, each of the Guarantors guaranteed the repayment of a portion of the Loan Agreement pursuant to a Limited Guaranty Agreement. Additionally, in connection with the parties’ entry into the Loan Agreement and to further secure amounts due thereunder, certain of the Guarantors pledged shares of common stock which they received at the closing to the Lender, with RAD2 pledging 124,824 shares of common stock; DBS pledging 37,437 shares of common stock; and Saxum pledging 26,936 shares of common stock.

 

The Loan Agreement also provides that with respect to the properties located in Glasscock County, Texas, which the Company obtained ownership of at the closing of the Acquisition (collectively, the “West Texas Properties”), the Company has the right to sell the West Texas Properties after (i) the Lender approves the purchase and sale agreement in its sole discretion, (ii) the Lender receives as a prepayment of the loan, 50% of the sales proceeds of the West Texas Properties, but in no event less than $2,000,000, and (iii) the balance of the sales proceeds of the West Texas Properties are deposited in the bank account that we are required to maintain with the Lender, to be used to pay certain principal payments of the note as approved by Lender in its sole discretion.

 

The Company agreed to pay the Lender a loan finance charge of $400,000 in connection with its entry into the Loan Agreement, with half due on the date the Company entered into the Loan Agreement and half due on or before the 180th day following the date of the Loan Agreement. As further consideration for agreeing to the terms of the Loan, the Company agreed to issue the Lender 15,612 shares of common stock. The Company recognized a $2.8 million note discount related to these transactions and other debt issuance costs and will amortize the discount and debt issuance costs over the term of the note.

 

As of March 31, 2017, the Company was not in compliance with certain covenants of the loan agreement, including requiring the Company to maintain a net worth of $30 million, and the balance of the loan due to IBC of $38.3 million (less unamortized debt issuance costs of approximately $2.2 million), was recognized as a short-term liability on the Company’s balance sheet as of March 31, 2017. The Company has also recognized approximately $30,000 in accrued interest as of March 31, 2017.

 

On September 8, 2017, the Company received a Notice of Default and Opportunity to Cure (the “Notice”) from IBC, stating that the Company was in default under its loan due to failing to make a required $425,000 loan payment on August 25, 2017 (the “Payment Default”). The Notice was also sent to the guarantors under the Loan Agreement. The Notice also cited the Company for several covenant defaults including exceeding a cap on monthly general and administrative expenses; falling below $30 million of net worth; failing to comply with certain post-closing covenants regarding the assignment of certain oil and gas interests, the execution of certain supplemental mortgages and the completion of certain curative title requirements; failing to pay costs and expenses required pursuant to the terms of the Loan Agreement; failing to meet the requirements of a cash flow test as described in greater detail in the Loan Agreement; and exceeding the loan to value determination provided for in the Loan Agreement. In order to cure the Payment Default described in the Notice, the Company was required to pay $425,000, as well as any attorney’s fees and/or late fees as determined by IBC, on or before September 18, 2017, which amount was not paid and to cure the covenant defaults, which covenant defaults were not cured.

 

Pursuant to extension agreements entered into with IBC, in or around December 2017 and January 2018, (a) IBC agreed to waive the Company’s obligation to make the August 30, 2017, $425,000 monthly principal payment originally due under the IBC loan; (b) the Company confirmed the amount outstanding under the IBC loan ($37,443,308 as of each extension); (c) IBC agreed that interest only payments would be due on September 30, 2017, October 30, 2017, November 30, 2017 and December 31, 2017, with principal payments of $425,000 per month to begin thereafter, which principal payments were not made; (d) the parties agreed that the amounts owed to IBC were payable on demand, provided that if no demand was made, such amounts would be payable by way of monthly payments of $425,000 of principal, plus accrued interest, with the remaining amount owed to IBC due at maturity (August 25, 2019); (e) that the amount owed to IBC will accrue interest at the rate of 2% per annum above the prime rate, subject to a floor of 5.5% (currently 6.25% per annum); (f) if the Company fails to make any payment due to IBC within 10 days of its due date, IBC is due a late payment of 5% of the amount past due (subject to a minimum of $10 and a maximum of $1,500 per late payment); and (g) the Company and the guarantors of the IBC loan released IBC from any claims against IBC as of the date of each of such extensions.

 

 F-20 
 

 

Notwithstanding the above extensions, the Company is still in default under the IBC loan, the entire amount of the IBC loan may be accelerated and IBC may take action to enforce its remedies under the loan agreement. The IBC loan is secured by substantially all of the Company’s assets and if IBC were to foreclose on our assets it would have a material adverse effect on our operations and may force us to seek bankruptcy protection.

 

As of March 31, 2018, the Company was not in compliance with certain covenants of the loan agreement, including requiring the Company to maintain a net worth of $30 million, the Company is in default of the terms of the loan, and the balance of the loan due to IBC of $36.9 million (less unamortized debt issuance costs of approximately $1.3 million), was recognized as a short-term liability on the Company’s balance sheet as of March 31, 2018. The Company also recognized approximately $39,000 in accrued interest as of March 31, 2018 related to this note.

 

NOTE 7 – DERIVATIVE LIABILITIES

 

The Company has determined that certain warrants the Company has issued contain provisions that protect holders from future issuances of the Company’s common stock at prices below such warrants’ respective exercise prices and these provisions could result in modification of the warrants’ exercise price based on a variable that is not an input to the fair value of a “fixed-for-fixed” option as defined under FASB ASC Topic No. 815 - 40. The warrants granted to Ironman PI Fund II, LP contain anti-dilution provisions that provide for a reduction in the exercise price of such warrants in the event that future common stock (or securities convertible into or exercisable for common stock) is issued (or becomes contractually issuable) at a price per share (a “Lower Price”) that is less than the exercise price of such warrant at the time. The amount of any such adjustment is determined in accordance with the provisions of the warrant agreement and depends upon the number of shares of common stock issued (or deemed issued) at the Lower Price and the extent to which the Lower Price is less than the exercise price of the warrant at the time.

 

Activities for derivative warrant instruments during the years ended March 31, 2017 and 2018 were as follows:

 

   Fair Value
Balance, March 31, 2016  $126,960 
      
Change in fair value   (105,298)
Balance, March 31, 2017   21,662 
Change in fair value   (21,657)
Balance, March 31, 2018  $5 

 

The fair value of the derivative warrants was calculated using the Black-Scholes pricing model. Variables used in the Black-Scholes pricing model as of March 31, 2018 include (1) discount rate of 2.09%, (2) expected term of 1 year, (3) expected volatility of 145.70%, and (4) zero expected dividends. Variables used in the Black-Scholes pricing model as of March 31, 2017 include (1) discount rate of 1.28, (2) expected term of 2 years, (3) expected volatility of 168.75%, and (4) zero expected dividends.

 

NOTE 8 – COMMITMENTS AND CONTINGENCIES

 

In August 2017, the Company ceased its use of this office space and moved its headquarters to 4040 Broadway, Suite 425, San Antonio, Texas. The Company is committed to the remaining lease payments for the Houston office space for approximately $346,000, assuming an early termination of the lease on July 31, 2019. The Company recorded monthly rent expense associated with the Houston lease through August 2017. In accordance with the accounting guidance in ASC 420-10-25-13 regarding exit or disposal cost obligations, as of August 2017, the Company recorded rent expense, within general and administrative expense, and accrued a liability of $302,289, which represents the fair value of costs that will continue to be incurred during the remaining term of the Houston lease without economic benefit to the Company. As of March 31, 2018, the carrying amount of the liability of $226,972 was included in accrued expenses on the Company’s balance sheet. In addition, the Company wrote-off $189,533 of mostly fully depreciated property and equipment that was not re-located to the San Antonio headquarters resulting in a loss of $3,368.

The Company’s oil and gas lease acreage is subject to expiration if the Company does not drill and hold such acreage by production or exercise options to extend such leases. As of March 31, 2018, the Company has 423 acres of unproved lease acreage that is set to expire during fiscal year 2019 unless drilled or otherwise extended by the Company.

 F-21 
 

 

Effective October 1, 2017, the Company entered into an agreement to sublease space in San Antonio, Texas from RAD2 Minerals, Ltd., an entity owned and controlled by Mr. Azar, the Company’s former Chief Executive Officer. Rent for 2017 was $5,000 per month and rent for 2018 is $7,500 per month. The agreement has been modified to month to month at $2,500 per month, effective July 1, 2018.

Legal Proceedings. From time to time suits and claims against Camber arise in the ordinary course of Camber’s business, including contract disputes and title disputes. Camber records reserves for contingencies when information available indicates that a loss is probable and the amount of the loss can be reasonably estimated.

 

Maranatha Oil Matter

 

In November 2015, Randy L. Robinson, d/b/a Maranatha Oil Co. sued the Company in Gonzales County, Texas (Cause No. 26160). The plaintiff alleged that it assigned oil and gas leases to the Company in April 2010, retaining a 4% overriding royalty interest and 50% working interest and that the Company failed to pay such overriding royalty interest or royalty interest. The interests relate to certain oil and gas properties which the Company subsequently sold to Nordic Oil USA in April 2013. The petition alleges causes of actions for breach of contract, failure to pay royalties, non-payment of working interest, fraud, fraud in the inducement of contract, money had and received, constructive trust, violation of theft liability act, continuing tort and fraudulent concealment. The suit seeks approximately $100,000 in amounts alleged owed, plus pre-and post-judgment interest. We have filed a denial to the claims.

 

Rubenstein Matter

 

On September 28, 2017, Aaron Rubenstein, a purported shareholder of the Company’s common stock, filed a lawsuit against the Company (as nominal defendant) and Richard N. Azar II, it’s then Chief Executive Officer and director (who has since resigned from both positions), RAD2 Management, LLC, RAD2 Minerals, Ltd. and Segundo Resources, LLC, each an entity owned and controlled by Mr. Azar, in the United States District Court, Western District of Texas (Case No. 5:17-cv-962-FB).  The suit seeks the recovery (for the benefit of the Company) of alleged short-swing profits from Mr. Azar and his related entities under Section 16(b) of the Exchange Act relating to various transactions involving Series B Preferred Stock of the Company in November 2016 and January 2017. Mr. Azar denies the existence of any short-swing profits and filed a denial with the court. The Company also filed a denial with the court.

 

Petroflow Matter

 

In October 2017, the Company agreed to pay directly and reimburse entities owned in part by Alan Dreeben, a former director of the Company, for legal fees and settlement payments expended in connection with the defense of Petroflow Energy Corporation v. Sezar Energy, L.P. and Brittany Energy, LLC, Case No. 16-CV-700-TCK;TLW, In the United States District Court – N.D. OK. The Company was the beneficiary through the release of interest in disputed lease interests from Petroflow to the Company that provides the Company with complete control over those properties to renew expired leases and to have 100% of the drilling rights related to those properties. Sezar Energy and Brittany Energy have assigned any interests they may have had in conjunction with litigation in exchange for the Company making the agreed settlement payments of $475,000 plus direct payments and reimbursement of the legal costs paid on behalf of the defendants by Mr. Dreeben. Total legal fees expended by such entities totaled $392,043, and the Company reimbursed such fees by issuing Mr. Dreeben 78,409 shares of common stock with a value of $0.20 per share in November 2017. In addition, the Company directly paid legal fees and settlement payments totaling $567,633. The total expense related to the Petroflow matter of $959,676 is included in General and Administrative expense on the statement of operations.

 

Employment Agreement. Effective November 1, 2012, the Company entered into an Employment Agreement with Anthony C. Schnur to serve as the Chief Financial Officer of the Company, which agreement was amended and restated effective December 12, 2012, in connection with his appointment as Chief Executive Officer. The agreement had a term of two years, expiring on October 31, 2014, provided that the agreement was automatically extended for additional one year terms, unless either party provided notice of their intent not to renew within the 30-day period prior to any automatic renewal date, and as neither party provided notice of their intent to terminate in fiscal 2015 or 2016, the agreement automatically extended for an additional one year term until October 31, 2016 and October 31, 2017, respectively, notwithstanding the termination of the agreement in connection with Mr. Schnur’s resignation on June 2, 2017, as discussed below. The Company agreed to pay Mr. Schnur a base annual salary of $310,000 during the term of the agreement, of which $290,000 is payable in cash and $20,000 is payable in shares of the Company’s common stock. The stock consideration due under the agreement is payable in quarterly installments at the end of each quarter, based on the stock price on the last day of each quarter. Mr. Schnur is also eligible for an annual bonus of up to 30% of his base salary in cash or stock.

 

 F-22 
 

 

The Employment Agreement was terminated in connection with Mr. Schnur’s resignation as Chief Executive Officer and director of the Company effective on June 2, 2017. In connection with the departure of Mr. Anthony C. Schnur as Chief Executive Officer and director of the Company effective June 2, 2017, the Company entered into a Severance Agreement and Release with Mr. Schnur (the “Release”), whereby (i) his employment agreement with the Company was terminated, (ii) he entered into a mutual release with the Company; (iii) the Company agreed to issue him 4,800 shares of unregistered common stock (to be issued in installments of 400 per month)(the “Settlement Shares”) and a monthly cash payment of $14,000 for twelve months; and (iv) he was granted reimbursement of the payment of his COBRA premiums through (a) the one year anniversary of the termination or (b) until he is eligible to participate in the health insurance plan of another employer, whichever is sooner, and provided that the amount of such health benefits shall reduce his monthly cash payment. On January 11, 2018, and effective as of the original date of the Release, the Company and Mr. Schnur entered into a First Amendment to Severance Agreement and Release (the “Release Amendment”), whereby the terms of the Release were changed to provide for among other things, the payment of $49,000 on or before January 12, 2018; $15,000 on or before the 15th of each month from February 2018 to July 2018; and $19,000 on or before August 15, 2018, and further provided for the issuance of the entire amount of the Settlement Shares within five days of the later of the date the Company’s stockholders approved the issuance of the Settlement Shares and the date the NYSE American approved the issuance of such shares. The payments owed as of March 31, 2018 of $79,025 have been accrued and included in Accrued Expenses on the balance sheet. The Settlement Shares were issued in February 2018.

 

NOTE 9 – INCOME TAXES

 

The Company recorded a benefit for income taxes of $0 and $15,000 for the years ended March 31, 2018 and 2017, respectively, as a result of the losses and change in valuation allowances for each year.

 

   2018  2017
 Current taxes:          
 Federal  $—      (15,000)
 State   —      —   
    —      (15,000)
 Deferred taxes:          
 Federal   —      —   
 State   —      —   
    —      —   
 Total  $—      (15,000)

 

The following is a reconciliation between actual tax expense (benefit) and income taxes computed by applying the U.S. federal income tax rate (31.5% for 2018 and 34% for 2017) to income from continuing operations before income taxes for the years ended March 31, 2018 and 2017:

 

   2018  2017
 Computed at expected tax rates  $(7,805,048)  $(30,307,001)
 Nondeductible expenses   91,439    237,099 
 Return to accrual true-up   —      (15,000)
 NOLs limitation resulting from change in control   —      15,134,586 
 Change in effective tax rates   (11,470,220)   —   
 Change in valuation allowance   19,183,829    14,935,316 
 Total  $—     $(15,000)

 

 F-23 
 

 

Tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred liabilities are presented below:

 

   At March 31,
   2018