As filed with the Securities and Exchange Commission on February 14, 2014
Registration No. 333-_______333-
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
FORM S-1
REGISTRATION STATEMENT
UNDER
THE SECURITIES ACT OF 1933
ENERJEX RESOURCES, INC.
(Exact name of registrant as specified in its charter)
| Nevada | 1311 | 88-0422242 | ||
(State or other jurisdiction of incorporation) | (Primary Standard Industrial Classification Code Number) | ( Identification No.) |
4040 Broadway, Suite 350
San Antonio, TX 78209
Telephone:(210) 451-5545
(Address, including zip code, and telephone number,
National Corporate Woods, Suite 350
202 South Minnesota Street
Carson City, NV 89703
Telephone: (888) 600-9540
(Name, address, including zip code, and telephone number,
Copies to:
Michael E. Pfau, Esq. Fernando Velez, Jr., Esq. Reicker, Pfau, Pyle & McRoy LLP 1421 State Street, Ste. B Santa Barbara, CA 93101 Telephone: (805) 966-2440 | Jonathan R. Zimmerman Alyn Bedford 2200 Wells Fargo Center 90 S. 7th Street Minneapolis, MN 55402-3901 Telephone: (612) 766-7000 |
Approximate dateDate of commencementCommencement of proposed saleProposed Sale to the public:
If any of the securities being registered on this Form are to be offered on a delayed or continuous basis pursuant to Rule 415 under the Securities Act of 1933, check the following box.
If this Form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, please check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.
If this Form is a post-effective amendment filed pursuant to Rule 462(c) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.
If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering.
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):
| Large accelerated filer | ¨ | |||||
| Non-accelerated filer | ¨ | Smaller reporting company | x | |||
CALCULATION OF REGISTRATION FEE
| Title of Securities to be Registered | Amount to be Registered | Proposed Maximum Offering Price Per Share(1) | Proposed Maximum Aggregate Offering Price (1) | Amount of Registration Fee (2) | ||||||||||||
| Common Stock ($0.001 par value) to be offered for resale by the selling stockholder | 1,390,000 | $ | 0.60 | $ | 834,000 | $ | 46.54 | |||||||||
Title of each class of securities to be registered | Amount to be registered | Proposed maximum offering price per unit | Proposed maximum aggregate offering price | Amount of registration fee(1) | ||||
| Series B Cumulative Redeemable Perpetual Preferred Stock, par value $0.001 per share | 300,000 | $25.00 | $7,500,000.00 | $1,030.40 |
| (1) |
The Registrantregistrant hereby amends this Registration Statementregistration statement on such date or dates as may be necessary to delay its effective date until the Registrantregistrant shall file a further amendment which specifically states that this Registration Statementregistration statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act, of 1933as amended, or until the Registration Statementregistration statement shall become effective on such date as the Securities and Exchange Commission, acting pursuant to said Section 8(a), may determine.
The information in this prospectus is not complete and may be changed. WeThese securities may not sell these securitiesbe sold until the registration statement filed with the Securities and Exchange Commission is effective. This prospectus is not an offer to sell these securities and it is not soliciting an offer to buy these securities in any state where the offer or sale is not permitted.
PROSPECTUS
SUBJECT TO COMPLETION, DATED February 14, 2014
ENERJEX RESOURCES, INC.
[·] Shares of [·]% Series B Cumulative Redeemable Perpetual Preferred Stock
$[·] - $ [·] Per Share
Liquidation Preference $25.00 Per Share
We are offering [·] shares of our [·]% Series B Cumulative Redeemable Perpetual Preferred Stock, which we refer to as the Series B Preferred Shares, or the Series B Preferred Stock.
Dividends on the Series B Preferred Stock are cumulative from the date of original issue and will be payable on the 31st day of each January, July and October and on the 30th day of April commencing [·], 2014 when, as and if declared by our board of directors. Dividends will be payable out of amounts legally available therefore at an initial rate equal to [·] per annum per $25.00 of stated liquidation preference per share. Before this offering, there has been no public market for the Series B Preferred Stock. The dividend rate and other terms of the Series B Preferred Stock will be negotiated between us and a representative of the underwriters. Factors that will be considered in determining the dividend rate and other terms of the Series B Preferred Stock include the history and prospects of EnerJex Resources, Inc., the dividend rates and other terms of recent offerings of similar securities and trading in those securities, general conditions in the securities markets at the time of the offering and such other factors that we and the representative deem relevant. We estimate that the dividend rate for the Series B Preferred Shares will be set within a range of approximately [·] % to [·]% per annum, but the final dividend rate for the offering of Series B Preferred Shares may be below or above this estimated range and will be set forth in the final prospectus.
Commencing on [·], 201[·], we may redeem, at our option, the Series B Preferred Shares, in whole or in part, at a cash redemption price of $[·] per share, plus any accrued and unpaid dividends to, but not including, the redemption date. The Series B Preferred Shares have no stated maturity, will not be subject to any sinking fund or other mandatory redemption, and will not be convertible into or exchangeable for any of our other securities.
Holders of the Series B Preferred Shares generally will have no voting rights except for limited voting rights if dividends payable on the outstanding Series B Preferred Shares are in arrears for six or more consecutive or non-consecutive quarters, and under certain other circumstances. The Series B Preferred Shares are a new issue of securities with no established trading market.
Northland Capital Markets and Euro Pacific Capital Inc. are acting as our underwriters in the public offering on a best efforts basis. The underwriters are not required to sell any specific number or dollar amount of Series B Preferred Stock, but will use their best efforts to sell the Series B Preferred Stock offered. We have agreed to pay the underwriters cash commissions equal to [l]% of the gross proceeds received by us, if any, in this offering. The offering is not contingent upon the occurrence of any event or sale of a minimum or maximum number of shares. We have also agreed to pay up to $[l] of the expenses of the underwriters in connection with this offering. Please see “Underwriting” in this prospectus for more information regarding our arrangements with the underwriters.
If we sell all [l] shares of Series B Preferred Stock we are offering pursuant to this prospectus and assuming an offering price of $[l] per share, the midpoint of the range shown above, we will receive a maximum of $[l] in gross proceeds and approximately $[l] in net proceeds, after deducting the underwriting commissions and estimated offering expenses payable by us.
However, because this is a best efforts, no minimum offering, the underwriters do not have an obligation to purchase any shares and, as a result, there is a possibility that we may not receive any proceeds from the offering. See “Use of Proceeds” in this prospectus. There is no arrangement for funds to be received in escrow, trust or similar arrangement.
We expect the Series B Preferred Stock will be ready for delivery in book-entry form through The Depositary Trust Company on or about [l], 2014.
Investing in our Series B Preferred Stock involves significant risks. You should carefully consider the risk factors beginning on page[·]of this prospectus before purchasing any of the Series B Preferred Stock offered by this prospectus.
NEITHER THE SECURITIES AND EXCHANGE COMMISSION NOR ANY STATE SECURITIES COMMISSION HAS APPROVED OR DISAPPROVED OF THESE SECURITIES OR DETERMINED IF THIS PROSPECTUS IS TRUTHFUL OR COMPLETE. ANY REPRESENTATION TO THE CONTRARY IS A CRIMINAL OFFENSE.
| Per Share | Total | |||||
| Public offering price | $ | $ | ||||
| Underwriting discounts and commissions | $ | $ | ||||
| Proceeds to us, before expenses | $ | $ |
The date of this prospectus is [·], 2014.
TABLE OF CONTENTS
| Page | ||||
| Prospectus Summary | 1 | |||
| Risk Factors | 5 | |||
| Special Note Regarding Forward-Looking Statements | 16 | |||
Determination & Offering Price Capitalization | ||||
| Use of Proceeds | 22 | |||
| Price Range of Common Stock and Series A Preferred Stock | ||||
Dividend Policy Selected Financial Data Ratio of Earnings to Fixed Charges | 23 | |||
| Management’s Discussion and Analysis of Financial Condition and Results of Operation | 23 | |||
| Business | 29 | |||
| Management | 36 | |||
| Security Ownership of Management and Principal Stockholders | 48 | |||
| Certain Relationships and Related Party Transactions | 49 | |||
| Description of Capital Stock | 50 | |||
Description of Our Series B Preferred Stock Description of Indebtedness | 52 | |||
| Material U.S. Federal Income Tax Consequences | 17 | |||
| Underwriting | 57 | |||
| Legal Matters | 58 | |||
| Experts | 58 | |||
| Where You Can Find More Information | 58 | |||
| Index to Financial Statements | 59 | |||
ABOUT THIS PROSPECTUS
This document does not constitute an offer to sell, or a solicitation of an offer to buy, any securities, in any jurisdiction in which, or from any person to whom, it is unlawful to make any such offer or solicitation in such jurisdiction. The securities are not being offered in any jurisdiction where the offer of such securities is not permitted.
You should rely only on the information contained in this prospectus. We have not, and the underwriters have not, authorized anyone to provide you with different information. If anyone provides you with different or inconsistent information, you should not rely on it. We are not, and the underwriters are not, making an offer to sell these securities in any jurisdiction where the offer or sale is not permitted or in which the person making that offer or solicitation is not qualified to do so or to anyone to whom it is unlawful to make an offer or solicitation. You should assume that the information appearing in this prospectus is accurate only as of the date on the front cover of this prospectus. Our business, financial condition, results of operations and prospects may have changed since that date. You should read this prospectus and the registration statement of which this prospectus is a part in their entirety before making an investment decision.
We further note that the representations, warranties and covenants made by us in any agreement that is filed as an exhibit to this prospectus were made solely for the benefit of the parties to such agreement, including, in some cases, for the purpose of allocating risk among the parties to such agreement, and should not be deemed to be a representation, warranty or covenant to you. Moreover, such representations, warranties or covenants were accurate only as of the date when made. Accordingly, such representations, warranties and covenants should not be relied on as accurately representing the current state of our affairs.
We are not making any representation to you regarding the legality of an investment in our securities by you under applicable law. You should consult with your own legal advisors as to the legal, tax, business, financial and related aspects of a purchase of our securities.
The information in this prospectus is complete and accurate only as of the date of this prospectus, regardless of the time of delivery of this prospectus or anythe time of issuance or sale of our common stock. Our business, financial condition, prospectsany securities.
The EnerJex Resources logo is the property of EnerJex Resources, Inc. or a subsidiary thereof. References herein to “$” and other information may have changed since this date.
In this prospectus, we refer to permit a public offering of the common stockinformation regarding potential markets for our products and other industry data. We believe that all such information has been obtained from reliable sources that are customarily relied upon by companies in our industry. However, we have not independently verified any such information.
Information contained on or possession or distributionaccessible through our website, www.enerjex.com does not constitute part of this prospectus in that jurisdiction. Persons who come into possession ofprospectus.
| i |
The registration statement containing this prospectus, in jurisdictions outsideincluding the United States are requiredexhibits to inform themselvesthe registration statement, provides additional information about and to observe any restrictions as to, this offeringus and the distribution ofsecurities offered under this prospectus applicable to those jurisdictions.
Securities and Exchange Commission offices mentioned under the heading “Where You Can Find More Information.”
Northland Capital Markets is the trade name for certain capital markets and investment banking services of Northland Securities, Inc., member FINRA/SIPC.
| ii |
PROSPECTUS SUMMARY
The items in the following summary are described in more detail laterprovides an overview of certain information contained elsewhere in this prospectus. Because this section is a summary, it does not contain all of the information that may be important to you or that you should consider before investing in our common stock. ForSeries B Preferred Stock. You should read this entire prospectus carefully before making a more complete understanding, you should carefully read the more detailed information set out in this prospectus, especially the risks of investingdecision about whether to invest in our common stock that we discuss underSeries B Preferred Stock. Unless the “Risk Factors” section, as well as the financial statements and the related notes to those statements included elsewhere in this prospectus.
Overview
We report our financial informationoperate as an independent exploration and production company focused on the basisacquisition and development of a March 31 fiscal year end. We have provided definitions for the oil and natural gas industry terms used in this prospectusproperties located in the “Glossary” beginning on page 77mid-continent region of this prospectus.
We were formerly known as Millennium Plastics Corporation is an oil and natural gas acquisition, exploration and development company. In August 2006, Millennium Plastics Corporation, following a reverse merger by and among us, Millennium Acquisition Sub (our wholly-owned subsidiary) and Midwest Energy, Inc., a Nevada corporation, or Midwest Energy, changed the focus of its business plan from the development of biodegradable plastic materials and entered into the oil and natural gas industry. In conjunction with the change, the company was renamed EnerJex Resources, Inc.
Proved Reserves Category | Gross STB(1) | Net STB(2) | Gross MCF(3) | Net MCF(4) | PV10(5) (before tax) | |||||||||||||||
| Proved, Developed Producing | 722,590 | 429,420 | - | - | $ | 6,691,550 | ||||||||||||||
| Proved, Developed Non-Producing | 146,620 | 95,560 | - | - | 1,459,280 | |||||||||||||||
| Proved, Undeveloped | 1,440,760 | 811,650 | - | - | 2,478,510 | |||||||||||||||
| Total Proved | 2,309,970 | 1,336,630 | - | - | $ | 10,629,340 | ||||||||||||||
EnerJex's corporate offices are located at any time. These shares are being registered with this registration statement, even though Paladin does not own them yet. On December 3, 2009, we authorized the issuance of 90,000 shares of our common stock to Paladin as a commitment fee. As of December 9, 2009, we had not sold any shares of common stock to Paladin under the SEDA.
Recent Developments
On July 23, 2013, EnerJex, BRE Merger Sub, Inc., a Delaware corporation and a wholly owned subsidiary of EnerJex (Merger Sub), and Black Raven Energy, Inc., a Nevada corporation (Black Raven), entered into an agreement and plan of merger (Merger Agreement) pursuant to register 1,390,000which Black Raven would be merged with and into Merger Sub and after which Black Raven would be a wholly owned subsidiary of EnerJex.
On September 27, 2013, the transactions contemplated by the Merger Agreement were successfully completed.
The following transactions were executed on September 27, 2013 per the terms of the Merger Agreement: (i) shares of ourcapital stock of Black Raven were converted into (a) cash totaling $207,067 and (b) 41,328,914 shares of EnerJex common stock, already issued(ii) all options under the Black Raven option plan were cancelled, and (iii) all warrants or other rights to or subject to issuance to the Selling Stockholder named in this prospectus for resale pursuant to this prospectus. The named selling stockholder may offerpurchase shares of ourcapital stock of Black Raven were converted into warrants to purchase EnerJex common stock. No fractional shares of EnerJex common stock were issued in connection with the Merger, and holders of Black Raven common stock were entitled to receive cash in lieu thereof. The board of directors and executive officers of EnerJex remained unchanged as a result of the closing of the Merger.
At closing of the transactions contemplated by the Merger Agreement, the previous stockholders of Black Raven owned approximately 38% of the outstanding voting stock of EnerJex and the previous stockholders of EnerJex owned approximately 62% of the outstanding voting stock of EnerJex.
Executive Offices
Our principal executive offices are located at 4040 Broadway, Suite 508, San Antonio, Texas 78209, and our telephone number is (210) 451-5545. Our website is www.enerjexresources.com. Additional information that may be obtained through public or private transactions.our website does not constitute part of this prospectus.
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THE OFFERING
The following is a brief description of certain terms of this offering and does not purport to be complete. For a more complete description of the terms of the Series B Preferred Stock, see “Description of Series B Preferred Stock” beginning on page [l] of this prospectus.
Securities we are offering: | [·] shares of [·]% Series B Cumulative Redeemable Perpetual Preferred Stock | ||||
| Series B Preferred Stock outstanding before offering: | None | ||||
| Series B Preferred Stock outstanding after offering: | [·] shares | ||||
Use of proceeds: | We intend to use the net proceeds of this offering for general corporate purposes, including capital expenditures to accelerate the development of our oil and natural gas properties. See “Use of Proceeds” on page [·] for further information. | ||||
Capital Market: | Our Series B Preferred Stock is not yet listed on an exchange, and there is not an established trading market for the shares. | ||||
| Best Efforts: | The underwriters are selling shares of the Series B Preferred Stock on a “best efforts” basis and are not required to sell any specific number or dollar amount of Series B Preferred Stock, but will use their best efforts to sell the Series B Preferred Stock offered in this prospectus. | ||||
| Dividends: | Holders of the Series B Preferred Stock will be entitled to receive, when and as declared by the | ||||
• | the terms of our senior shares (as defined below) or our agreements, including our credit facilities, at any time prohibit the current payment of dividends; | ||||
| • | we have earnings; | ||||
| • | there are funds legally available for the payment of such dividends; or | ||||
| • | the dividends are declared by our board of directors. | ||||
All payments of dividends made to the holders of Series B Preferred Stock will be credited against the previously accrued dividends on such shares of Series B Preferred Stock. We will | |||||
| Optional Redemption: | We may not redeem the Series B Preferred Stock prior to [l], except pursuant to the special redemption upon a Change of Ownership or Control discussed below. On and after [l], we may redeem the Series B Preferred Stock for cash at our option, from time to time, in whole or in part, at a redemption price of $25.00 per share, plus accrued and unpaid dividends (whether or not earned or declared) to the redemption date. | |
Special Redemption Upon Change of Ownership or Control: | ||
The Series B Preferred Stock does not have any stated maturity date and will not be subject to any sinking fund or mandatory redemption provisions except for redemption at our option (or the option of the acquiring entity) under some circumstances upon a Change of Ownership or Control as described above or after [ | ||
| Ranking: | The Series B Preferred Stock will rank: (i) senior to our common stock | |
| Liquidation Preference: | If we liquidate, dissolve or wind up our operations, the holders of our Series B Preferred Stock will have the right to receive $25.00 per share, plus all accrued and unpaid dividends (whether or not earned or declared) to and including the date of payment, before any payments are made to the holders of our common stock and any other of our junior shares. The rights of the holders of the Series B Preferred Stock to receive the liquidation preference will be subject to the proportionate rights of holders of each other future series or class of parity shares and subordinate to the rights of senior shares. | |
| Voting Rights: | Holders of the Series B Preferred Stock will generally only be entitled to vote on changes to our articles of incorporation that would be materially adverse to the rights of holders of Series B Preferred Stock provided that the creation of a class of parity shares or an increase of the authorized number of shares of Series B Preferred Stock shall be deemed to not materially or adversely affect such rights. However, if cash dividends on any outstanding Series B Preferred Stock have not been paid in full for any quarterly dividend period for any six consecutive or non-consecutive quarterly periods, the holders of the Series B Preferred Stock, voting separately as a class with holders of all other series of parity shares upon which like voting rights have been conferred and are exercisable, will have the right to elect two directors to serve on our board of directors in addition to those directors then serving on our board of directors until such time as the dividend arrearage is eliminated. | |
| Material U.S. Federal Income Tax Consequences: | The material U.S. federal income tax consequences of purchasing, owning and disposing of Series C Preferred Stock are described | |
| Form: | The Series B Preferred Stock will be issued and maintained in book-entry form registered in the name of the nominee of The Depository Trust Company & Clearing Corporation, except under limited circumstances. | |
Conversion Rights: | The SeriesB Preferred Stock is not convertible into common stock. | |
| Risk Factors: | Investing in the Series B Preferred Stock involves substantial risks. You should carefully review and consider the “Risk Factors” section of this prospectus for a discussion of factors |
| 4 |
Six Months Ended September 30, | Year Ended March 31, | Year Ended March 31, | Year Ended March 31, | From Inception (December 30, 2005) through March 31, | ||||||||||||||||||||
2009 | 2008 | 2009 | 2008 | 2007 | 2006 | |||||||||||||||||||
| (Unaudited) | (Unaudited) | (Audited) | (Audited) | (Audited) | (Audited) | |||||||||||||||||||
| Statement of Operations: | ||||||||||||||||||||||||
| Revenue | ||||||||||||||||||||||||
| Oil and natural gas activities | $ | 2,789,179 | $ | 3,467,742 | $ | 6,436,805 | $ | 3,602,798 | $ | 90,800 | $ | 2,142 | ||||||||||||
| Expenses | ||||||||||||||||||||||||
| Direct costs | 864,835 | 1,531,300 | 2,637,333 | 1,795,188 | 172,417 | 14,599 | ||||||||||||||||||
| Repairs on oil and natural gas equipment | — | — | 911,293 | — | 165,603 | 40,436 | ||||||||||||||||||
| Depreciation, depletion and Amortization | 445,895 | 718,048 | 4,777,723 | 935,330 | 23,978 | 825 | ||||||||||||||||||
| Professional fees | 419,139 | 294,785 | 1,320,332 | 1,226,998 | 302,071 | 50,490 | ||||||||||||||||||
| Salaries | 552,989 | 494,426 | 849,340 | 1,703,099 | 288,016 | — | ||||||||||||||||||
| Administrative expense | 455,316 | 836,430 | 1,392,645 | 887,872 | 182,773 | 21,700 | ||||||||||||||||||
| Impairment of oil and natural gas Properties | — | — | — | — | 273,959 | 468,081 | ||||||||||||||||||
| Impairment of goodwill | — | — | — | — | 677,000 | — | ||||||||||||||||||
| Total expenses | 2,738,174 | 3,874,989 | 11,888,666 | 6,548,487 | 2,085,817 | 596,131 | ||||||||||||||||||
| Income (loss) from operations | 51,005 | (407,247 | ) | (5,451,861 | ) | (2,945,689 | ) | (1,995,017 | ) | (593,989 | ) | |||||||||||||
| Other income (expense): | ||||||||||||||||||||||||
| Interest expense | (353,565 | ) | (532,624 | ) | (882,426 | ) | (1,882,246 | ) | (8,434 | ) | (38 | ) | ||||||||||||
| Loan interest accretion | (279,490 | ) | (2,567,379 | ) | (2,814,095 | ) | — | — | — | |||||||||||||||
| Management fee revenue | 75,291 | — | — | — | — | — | ||||||||||||||||||
| Gain on repurchase of debentures | 406,500 | — | — | — | — | — | ||||||||||||||||||
| Gain on liquidation of hedging instrument | — | — | 3,879,050 | — | — | — | ||||||||||||||||||
| Other | — | — | (37,736 | ) | — | 348 | 1,159 | |||||||||||||||||
| Total other income (expense) | (151,264 | ) | (3,100,003 | ) | 144,793 | (1,882,246 | ) | (8,086 | ) | 1,121 | ||||||||||||||
| Net income (loss) | $ | (100,259 | ) | $ | (3,507,250 | ) | $ | (5,307,068 | ) | $ | (4,827,935 | ) | $ | (2,003,103 | ) | $ | (592,868 | ) | ||||||
| Weighted average number of common shares outstanding – basic and fully diluted | 4,557,760 | 4,442,930 | 4,443,249 | 4,284,143 | 2,448,318 | 1,712,609 | ||||||||||||||||||
| Net income (loss) per share – basic | $ | (0.02 | ) | $ | (0.79 | ) | $ | (1.19 | ) | $ | (1.13 | ) | $ | (0.82 | ) | $ | (0.35 | ) | ||||||
Six Months Ended September 30, | Year Ended March 31, | Year Ended March 31, | Year Ended March 31, | From Inception (December 30, 2005) through March 31, | ||||||||||||||||||||
2009 | 2008 | 2009 | 2008 | 2007 | 2006 | |||||||||||||||||||
| (Unaudited) | (Unaudited) | (Audited) | (Audited) | (Audited) | (Audited) | |||||||||||||||||||
| Statement of Cash Flows: | ||||||||||||||||||||||||
| Cash provided by (used in) operating activities | $ | 1,149,545 | $ | (356,550 | ) | $ | 3,686,582 | $ | (408,494 | ) | $ | $(1,435,559 | ) | $ | (60,786 | ) | ||||||||
| Cash used in investing activities | (180,684 | ) | (2,281,699 | ) | (3,027,203 | ) | (9,357,020 | ) | (151,180 | ) | (767,550 | ) | ||||||||||||
Cash provided by financing Activities | (1,006,900 | ) | 1,951,215 | (1,482,798 | ) | 10,617,025 | 1,095,800 | 1,418,768 | ||||||||||||||||
Increase (decrease) in cash and cash equivalents | (38,039 | ) | (687,034 | ) | (823,419 | ) | 851,511 | (490,939 | ) | 590,432 | ||||||||||||||
Cash and cash equivalents, beginning | 127,585 | 951,004 | 951,004 | 99,493 | 590,432 | — | ||||||||||||||||||
| Cash and cash equivalents, end | $ | 89,546 | $ | 263,970 | $ | 127,585 | $ | 951,004 | $ | 99,493 | $ | 590,432 | ||||||||||||
| Supplemental disclosures: | ||||||||||||||||||||||||
| Interest paid | $ | 151,334 | $ | 505,617 | $ | 768,053 | $ | 733,972 | $ | 5,407 | $ | 38 | ||||||||||||
| Income tax paid | $ | — | $ | - | $ | — | $ | — | $ | — | $ | — | ||||||||||||
| Non-cash transactions: | ||||||||||||||||||||||||
Share-based payment issued for services | $ | — | $ | 79,455 | $ | — | $ | 280,591 | $ | 558,000 | $ | 33,000 | ||||||||||||
Shares issued for compensation and services | $ | 494,750 | — | |||||||||||||||||||||
Share-based payments issued for oil and gas properties | $ | — | $ | — | $ | — | $ | — | $ | 200,000 | $ | — | ||||||||||||
| Principal increase on debentures | $ | 214,707 | $ | — | $ | — | $ | — | $ | — | $ | — | ||||||||||||
Shares issued for interest on debentures | $ | 5,368 | $ | — | $ | — | $ | — | $ | — | $ | — | ||||||||||||
| Asset retirement obligation | $ | 4,281 | $ | 246,871 | $ | — | $ | — | $ | — | $ | — | ||||||||||||
At September 30, | At March 31, | At March 31, | At March 31, | At March 31, | ||||||||||||||||
| 2009 | 2009 | 2008 | 2007 | 2006 | ||||||||||||||||
| (Unaudited) | (Audited) | (Audited) | (Audited) | (Audited) | ||||||||||||||||
| Total Assets | $ | 7,333,151 | $ | 7,680,178 | $ | 10,867,829 | $ | 492,507 | $ | 922,486 | ||||||||||
| Total Liabilities | 10,724,916 | 11,473,802 | 9,433,837 | 537,097 | 71,586 | |||||||||||||||
| Stockholders’ Equity (deficit) | $ | (3,391,765 | ) | $ | (3,793,624 | ) | $ | 1,433,992 | $ | (44,590 | ) | $ | 850,900 | |||||||
RISK FACTORS
Investing in our common stock involvessecurities has a highsignificant degree of risk. YouBefore you invest in the Series B Preferred Stock offered by this prospectus, you should carefully consider the following risk factors, as well asrisks described below, in addition to the other information presented in this prospectus, before deciding whether to invest in shares of our common stock.prospectus. If any of the following risks actually occur, they could seriously harm our business, financial condition, operating results and prospects would suffer. In that case,of operations or cash flows. This could cause the trading price of our common stock would likelySeries B Preferred Stock to decline and you mightcould lose all or part of your investmentinvestment.
Risks Related to Ownership of Our Series B Preferred Stock
The price of our Series B Preferred Stock may be volatile.
We expect the price of our common stock and Series B Preferred Stock to be subject to fluctuations as a result of a variety of factors, including factors beyond our control. These factors include:
| • | changing conditions in fuel markets; | |
| • | changes in financial estimates by securities analysts; | |
| • | changes in market valuations of comparable companies; | |
| • | additions or departures of key personnel; | |
| • | future sales of our capital stock; | |
| • | tax and other regulatory developments; | |
| • | market liquidity; | |
| • | particularly with respect to our Series B Preferred Stock, prevailing interest rates; | |
| • | the market for similar securities | |
| • | general economic conditions; and | |
| • | our financial condition, performance and prospects. | |
| • | our ability to develop and complete facilities, and to introduce and market the energy created by such facilities to economically viable production volumes in a timely manner; and | |
| • | other factors discussed in this “Risk Factors” section and elsewhere in this prospectus. |
Ownership of the our common stock and Series A Preferred Stock is highly concentrated, and such concentration may prevent you and other stockholders from influencing significant corporate decisions and may result in conflicts of interest that could cause the combined company's stock price to decline.
EnerJex's directors and executive officers, together with their respective affiliates, beneficially own or control more than 60% of the Company (see the sections entitled "Principal Stockholders of EnerJex" beginning on page [Ÿ] for more information on the estimated ownership of the company). Accordingly, these directors, executive officers and their affiliates, acting individually or as a group, have substantial influence over the outcome of a corporate action of requiring stockholder approval, including the election of directors, any merger, consolidation or sale of all or substantially all of our assets or any other significant corporate transaction. These stockholders also may exert influence in delaying or preventing a change in control of the Company, even if such change in control would benefit the other stockholders of the Company. In addition, the significant concentration of stock ownership may affect adversely the market value of EnerJex's common stock and Series B Preferred Stock due to investors' perception that conflicts of interest may exist or arise.
Anti-takeover provisions in the our charter and bylaws may prevent or frustrate attempts by stockholders to change the board of directors or management and could make a third-party acquisition of the combined company difficult.
Our amended and restated articles of incorporation and bylaws, as amended, contain provisions that may discourage, delay or prevent a merger, acquisition or other change in control that stockholders may consider favorable, including transactions in which stockholders might otherwise receive a premium for their shares. These provisions could limit the price that investors might be willing to pay in the future for shares of our common stock, and have a negative effect on the price at which shares of our Series B Preferred Stock will trade.
We could be prevented from paying dividends on the Series B Preferred Stock.
Although dividends on the Series B Preferred Stock are cumulative and will accrue until paid, you will receive cash dividends on the Series B Preferred Stock only if we have funds legally available for the payment of dividends and such payment is not restricted or prohibited by law, the terms of any senior shares, or any documents governing our indebtedness. Our business may not generate sufficient cash flow from operations to enable us to pay dividends on the Series B Preferred Stock when payable. In addition, future debt, contractual covenants or arrangements we enter into may restrict or prevent future dividend payments. Accordingly, there is no guarantee that we will be able to pay any cash dividends on our Series B Preferred Stock.
The Series B Preferred Stock has not been rated and will be subordinated to all of our existing and future debt.
The Series B Preferred Stock has not been rated by any nationally recognized statistical rating organization. In addition, with respect to dividend rights and rights upon our liquidation, winding-up or dissolution, the Series B Preferred Stock will be subordinated to all of our existing and future debt. We may also incur additional indebtedness in the future to finance potential acquisitions or other activities and the terms of the Series B Preferred Stock do not require us to obtain the approval of the holders of the Series B Preferred Stock prior to incurring additional indebtedness. As a result, our existing and future indebtedness may be subject to restrictive covenants or other provisions that may prevent or otherwise limit our ability to make dividend or liquidation payments on our Series B Preferred Stock. Upon our liquidation, our obligations to our creditors would rank senior to our Series B Preferred Stock and would be required to be paid before any payments could be made to holders of our Series B Preferred Stock.
The Series B Preferred Stock may be subordinated to our future equity issuances.
With the approval of holders of a majority of the issued and outstanding shares of Series B Preferred Stock, we may be able to issue shares of equity securities that have rights to dividends and liquidation that are senior to those of the holders of shares of the Series B Preferred Stock. If we obtained such approval and issued such future senior securities, then our obligations to holders of such future senior securities would be superior to those of the holders of shares of the Series B Preferred Stock, and we would be required to make payments to holders of such future senior securities before we could make any payments to holders of our Series B Preferred Stock.
Investors should not expect us to redeem the Series B Preferred Stock on the date the Series B Preferred Stock becomes redeemable or on any particular date afterwards.
We may not redeem the Series B Preferred Stock prior to [·]. On and after [·], we may redeem the Series B Preferred Stock for cash at our option, from time to time, in whole or in part, at a redemption price of $25.00 per share, plus accrued and unpaid dividends (whether or not earned or declared) to the redemption date. The Series B Preferred Stock does not have any stated maturity date and will not be subject to any sinking fund or mandatory redemption provisions. Any decision we may make at any time to redeem the Series B Preferred Stock will depend upon, among other things, our evaluation of our capital position, including the composition of our stockholders’ equity and general market conditions at that time.
Holders of Series B Preferred Stock have extremely limited voting rights.
Except as expressly stated in the certificate of designations governing the Series B Preferred Stock, as a holder of Series B Preferred Stock, you will not have any relative, participating, optional or other special voting rights and powers and your approval will not be required for the taking of any corporate action other than as provided in the certificate of designations. For example, your approval would not be required for any merger or consolidation in which we may become involved or any sale of all or substantially all of our assets except to the extent that such transaction materially adversely changes the express powers, preferences, rights or privileges of the holders of Series B Preferred Stock. The provisions relating to the Series B Preferred Stock do not afford the holders of the Series B Preferred Stock protection in the event of a highly leveraged or other transaction, including a merger or the sale, lease or conveyance of all or substantially all of our assets or business, that might adversely affect the holders of the Series B Preferred Stock, so long as the terms and rights of the holders of Series B Preferred Stock are not materially and adversely changed.
The issuance of future offerings of preferred stock may adversely affect the value of our Series B Preferred Stock.
Our articles of incorporation, as amended, currently authorizes us to issue up to 25,000,000 shares of preferred stock in one or more series on terms that may be determined at the time of issuance by our board of directors. We may issue other classes of preferred shares that would rank on parity with or senior to the Series B Preferred Stock as to dividend rights or rights upon liquidation, winding up or dissolution. The creation and subsequent issuance of additional classes of preferred shares that, with the consent of a majority of the holders of the Series B Preferred Stock, would be senior to or on parity with our Series B Preferred Stock would dilute the interests of the holders of Series B Preferred Stock and any issuance of preferred stock that is senior to the Series B Preferred Stock could affect our ability to pay dividends on, redeem or pay the liquidation preference on the Series B Preferred Stock.
Holders of the Series B Preferred Stock may be unable to use the dividends-received deduction.
Distributions paid to corporate U.S. holders of the Series B Preferred Stock may be eligible for the dividends-received deduction if we have current or accumulated earnings and profits, as determined for U.S. federal income tax purposes. We do not currently have accumulated earnings and profits. Additionally, we may not have sufficient current earnings and profits during future fiscal years for the distributions on the Series B Preferred Stock to qualify as dividends for U.S. federal income tax purposes. If the distributions fail to qualify as dividends, U.S. holders would be unable to use the dividends-received deduction. If any distributions on the Series B Preferred Stock with respect to any fiscal year are not eligible for the dividends-received deduction because of insufficient current or accumulated earnings and profits, it is possible that the market value of the Series B Preferred Stock might decline.
Non-U.S. Holders may be subject to U.S. income tax with respect to gain on disposition of their Series B Preferred Stock.
If we are a U.S. real property holding corporation at any time within the five-year period preceding a disposition of Series B Preferred Stock by a non-U.S. holder or the holder’s holding period of the shares disposed of, whichever period is shorter, such non-U.S. holder may be subject to U.S. federal income tax with respect to gain on such disposition. If we are a U.S. real property holding corporation, which we expect we are, so long as the Series B Preferred Stock is regularly traded on an established securities market, a non-U.S. holder will not be subject to U.S. federal income tax on the disposition of the Series B Preferred Stock unless the holder beneficially owns (directly or by attribution) more than 5% of the total fair market value of the Series B Preferred Stock at any time during the five-year period ending either on the date of disposition of such interest or other applicable determination date. For additional information concerning these matters, see “Material U.S. Federal Income Tax Consequences.”
| 6 |
Our ability to use net operating loss carryforwards to offset future taxable income may be subject to certain limitations.
We currently have net operating loss carryforwards that may be available to offset future taxable income. However, changes in the ownership of our stock (including certain transactions involving our stock that are outside of our control) could result (or may have already resulted) in an “ownership change” within the meaning of Section 382 of the Internal Revenue Code of 1986, as amended, which may significantly limit our ability to utilize our net operating loss carryforwards. To the extent an ownership change has occurred or were to occur in the future, it is possible that the limitations imposed on our ability to use pre-ownership change losses could cause a significant net increase in our common stock. The risks described below are not the only ones we face. Additional risks that we currently do not know about or that we currently believeU.S. federal income tax liability and could cause U.S. federal income taxes to be immaterialpaid earlier than otherwise would be paid if such limitations were not in effect.
Our Series B Preferred Stock is not convertible and if the price of our common stock increase, then holders of Series B Preferred Stock may also impairnot realize a corresponding increase in the value of such Series B Preferred Shares.
Our Series B Preferred Stock is not convertible into our operationscommon stock and business results.
Risks Associated withRelated to the Oil and Natural Gas Industry and Our Business
in General
This next discussion of risk factors relates to the oil and natural gas industry and our business in general.
Declining economic conditions and worsening geopolitical conditions could negatively impact our business
Our operations are affected by local, national and worldwide economic conditions. Markets in the United States and elsewhere have been experiencing extreme volatility and disruption for more than 12 months,5 years, due in part to the financial stresses affecting the liquidity of the banking system and the financial markets generally. In recent months, this volatility and disruption has reached unprecedented levels. The consequences of a potential or prolonged recession may include a lower level of economic activity and uncertainty regarding energy prices and the capital and commodity markets.
In addition, actual and attempted terrorist attacks in the United States, Middle East, Southeast Asia and Europe, and war or armed hostilities in the Middle East, the Persian Gulf, North Africa, Iran, North Korea or elsewhere, or the fear of such events, could further exacerbate the volatility and disruption to the financial markets and economy.
While the ultimate outcome and impact of the current economic conditions cannot be predicted, a lower level of economic activity might result in a decline in energy consumption, which may materially adversely affect the price of oil, our revenues, liquidity and future growth. Instability in the financial markets, as a result of recession or otherwise, also may affect the cost of capital and our ability to raise capital.
The oil and natural gas business involves numerous uncertainties and operating risks that can prevent us from realizing profits and can cause substantial losses.
Our development, exploitation and exploration activities may be unsuccessful for many reasons, including weather, cost overruns, equipment shortages and mechanical difficulties. Moreover, the successful drilling of a well does not ensure a profit on investment. A variety of factors, both geological and market-related, can cause a well to become uneconomical or only marginally economical. In addition to their cost, unsuccessful wells can hurt our efforts to replace reserves.
The oil business involves a variety of operating risks, including:
| ·unexpected operational events and/or conditions; |
| ·reductions in oil prices; |
| ·limitations in the market for oil; |
| ·adverse weather conditions; |
| ·facility or equipment malfunctions; |
| ·title problems; |
| ·oil and gas quality issues; |
| ·pipe, casing, cement or pipeline failures; |
| ·natural disasters; |
| ·fires, explosions, blowouts, surface cratering, pollution and other risks or accidents; |
| ·environmental hazards, such as oil spills, pipeline ruptures and discharges of toxic gases; |
| ·compliance with environmental and other governmental requirements; and |
| ·uncontrollable flows of oil or well fluids. |
If we experience any of these problems, it could affect well bores, gathering systems and processing facilities, which could adversely affect our ability to conduct operations. We could also incur substantial losses as a result of:
| ·injury or loss of life; |
| ·severe damage to and destruction of property, natural resources and equipment; |
| ·pollution and other environmental damage; |
| ·clean-up responsibilities; |
| ·regulatory investigation and penalties; |
| ·suspension of our operations; and |
| ·repairs to resume operations |
Because we use third-party drilling contractors to drill our wells, we may not realize the full benefit of worker compensation laws in dealing with their employees. Our insurance does not protect us against all operational risks. We do not carry business interruption insurance at levels that would provide enough funds for us to continue operating without access to other funds. For some risks, we may not obtain insurance if we believe the cost of available insurance is excessive relative to the risks presented. In addition, pollution and environmental risks generally are not fully insurable. If a significant accident or other event occurs and is not fully covered by insurance, it could impact our operations enough to force us to cease our operations.
Drilling wells is speculative, and any material inaccuracies in our forecasted drilling costs, estimates or underlying assumptions will materially affect our business.
Developing and exploring for oil and natural gas involves a high degree of operational and financial risk, which precludes definitive statements as to the time required and costs involved in reaching certain objectives. The budgeted costs of drilling, completing and operating wells are often exceeded and can increase significantly when drilling costs rise due to a tightening in the supply of various types of oilfield equipment and related services. Drilling may be unsuccessful for many reasons, including geological conditions, weather, cost overruns, equipment shortages and mechanical difficulties. Moreover, the successful drilling of an oil well does not ensure a profit on investment. Exploratory wells bear a much greater risk of loss than development wells. Substantially all of EnerJex's wells drilled through December 31, 2013 have been development wells, while a majority of the wells drilled by Black Raven have been considered by Black Raven to be development wells. A variety of factors, both geological and market-related, can cause a well to become uneconomical or only marginally economic. Our initial drilling and development sites, and any potential additional sites that may be developed, require significant additional exploration and development, regulatory approval and commitments of resources prior to commercial development. If our actual drilling and development costs are significantly more than our estimated costs, we may not be able to continue our business operations as proposed and would be forced to modify our plan of operation.
Development of our reserves, when established, may not occur as scheduled and the actual results may not be as anticipated. Drilling activity and lack of access to economically acceptable capital may result in downward adjustments in reserves or higher than anticipated costs. Our estimates will be based on various assumptions, including assumptions over which we have no control and assumptions required by the SEC relating to oil prices, drilling and operating expenses, capital expenditures, taxes and availability of funds. We have limited control over our operations that affect, among other things, acquisitions and dispositions of properties, availability of funds, use of applicable technologies, hydrocarbon recovery efficiency, drainage volume and production decline rates that are part of these estimates and assumptions and any variance in our operations that affects these items within our control may have a material effect on reserves. The process of estimating our oil reserves is extremely complex, and requires significant decisions and assumptions in the evaluation of available geological, geophysical, engineering and economic data for each reservoir. Our estimates may not be reliable enough to allow us to be successful in our intended business operations. Our actual production, revenues, taxes, development expenditures and operating expenses will likely vary from those anticipated. These variances may be material.
Unless we replace our oil and natural gas reserves, our reserves and production will decline, which would adversely affect our cash flows and income.
Unless we conduct successful development, exploitation and exploration activities or acquire properties containing proved reserves, our proved reserves will decline as those reserves are produced. Producing oil reservoirs generally are characterized by declining production rates that vary depending upon reservoir characteristics and other factors. Our future oil and gas production, and, therefore our cash flow and income, are highly dependent on our success in efficiently developing and exploiting our current reserves and economically finding or acquiring additional recoverable reserves. We may be unable to make such acquisitions because we are:
| ·unable to identify attractive acquisition candidates or negotiate acceptable purchase contracts with them; |
| ·unable to obtain financing for these acquisitions on economically acceptable terms; or |
| ·outbid by competitors. |
If we are unable to develop, exploit, find or acquire additional reserves to replace our current and future production, our cash flow and income will decline as production declines, until our existing properties would be incapable of sustaining commercial production.
Our decision to acquire a property will depend in part on the evaluation of data obtained from production reports and engineering studies, geophysical and geological analyses and seismic and other information, the results of which are often incomplete or inconclusive.
Our reviews of acquired properties can be inherently incomplete because it is not always feasible to perform an in-depth review of the individual properties involved in each acquisition. Even a detailed review of records and properties may not necessarily reveal existing or potential problems, nor will it permit a buyer to become sufficiently familiar with the properties to assess fully their deficiencies and potential. Inspections may not always be performed on every well, and environmental problems, such as ground water contamination, plugging or orphaned well liability are not necessarily observable even when an inspection is undertaken.
We must obtain governmental permits and approvals for drilling operations, which can result in delays in our operations, be a costly and time consuming process, and result in restrictions on our operations.
Regulatory authorities exercise considerable discretion in the timing and scope of well drilling permit issuances in the region in which we operate. Compliance with the requirements imposed by these authorities can be costly and time consuming and may result in delays in the commencement or continuation of our exploration or production operations and/or fines. Regulatory or legal actions in the future may materially interfere with our operations or otherwise have a material adverse effect on us. In addition, we are often required to prepare and present to federal, state or local authorities data pertaining to the effect or impact that a proposed project may have on the environment, threatened and endangered species, and cultural and archaeological artifacts. Accordingly, the well drilling permits we need may not be issued, or if issued, may not be issued in a timely fashion, or may involve requirements that restrict our ability to conduct our operations or to do so profitably.
Cost and availability of drilling rigs, equipment, supplies, personnel and other services could adversely affect our ability to execute on a timely basis our development, exploitation and exploration plans.
Shortages or an increase in cost of drilling rigs, equipment, supplies or personnel could delay or interrupt our operations, which could impact our financial condition and results of operations. Drilling activity in the geographic areas in which we conduct drilling activities may increase, which would lead to increases in associated costs, including those related to drilling rigs, equipment, supplies and personnel and the services and products of other vendors to the industry. Increased drilling activity in these areas may also decrease the availability of rigs. We do not have any contracts for drilling rigs and drilling rigs may not be readily available when we need them. Drilling and other costs may increase further and necessary equipment and services may not be available to us at economical prices.
Our exposure to possible leasehold defects and potential title failure could materially adversely impact our ability to conduct drilling operations.
We obtain the right and access to properties for drilling by obtaining oil and natural gas leases either directly from the hydrocarbon owner, or through a third party that owns the lease. The leases may be taken or assigned to us without title insurance. There is a risk of title failure with respect to such leases, and such title failures could materially adversely impact our business by causing us to be unable to access properties to conduct drilling operations.
We operate in a highly competitive environment and our competitors may have greater resources than do we.
The oil and natural gas industry is intensely competitive and we compete with other companies, many of which are larger and have greater financial, technological, human and other resources. Many of these companies not only explore for and produce crude oil and/or natural gas, but also carry on refining operations and market petroleum and other products on a regional, national or worldwide basis. Such companies may be able to pay more for productive oil properties and exploratory prospects or define, evaluate, bid for and purchase a greater number of properties and prospects than our financial or human resources permit. In addition, such companies may have a greater ability to continue exploration activities during periods of low oil market prices. Our ability to acquire additional properties and to discover reserves in the future will be dependent upon our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment. If we are unable to compete, our operating results and financial position may be adversely affected.
Oil and natural gas prices are volatile. Future volatility may cause negative change in our cash flows which may result in our inability to cover our operating or capital expenditures.
Our future revenues, profitability, future growth and the carrying value of our properties is anticipated to depend substantially on the prices we may realize for our oil and natural gas production. Our realized prices may also affect the amount of cash flow available for operating or capital expenditures and our ability to borrow and raise additional capital.
Oil and natural gas prices are subject to wide fluctuations in response to relatively minor changes in or perceptions regarding supply and demand. Historically, the markets for oil and natural gas have been volatile, and they are likely to continue to be volatile in the future. Among the factors that can cause this volatility are:
| · | Commodities speculators; | |
| · | local, national and worldwide economic conditions; | |
| · | worldwide or regional demand for energy, which is affected by economic conditions; | |
| · | the domestic and foreign supply of oil; weather conditions; | |
| · | natural disasters; | |
| · | acts of terrorism; | |
| · | domestic and foreign governmental regulations and taxation; | |
| · | political and economic conditions in oil producing countries, including those in the Middle East and South America; | |
| · | impact of the U.S. dollar exchange rates on oil prices; | |
| · | the availability of refining capacity; | |
| · | actions of the Organization of Petroleum Exporting Countries, or OPEC, and other state controlled oil companies relating to oil price and production controls; and | |
| · | the price and availability of other fuels. |
It is impossible to predict oil and gas price movements with certainty. A drop in prices may not only decrease our future revenues on a per unit basis but also may reduce the amount of oil and gas that we can produce economically. A substantial or extended decline in oil and gas prices may materially and adversely affect our future business enough to force us to cease our business operations. In addition, our reserves, financial condition, results of operations, liquidity and ability to finance and execute planned capital expenditures will also suffer in such a price decline.
Lower prices for oil and natural gas reduce demand for our services and could have a material adverse effect on our revenue and profitability.
Benchmark crude prices peaked at over $140 per barrel in July 2008 and then declined to approximately $111 per barrel at year-end 2012. During 2013, the benchmark for crude prices fluctuated between the high $[·.] per barrel and high $[·
Our business is affected by local, national and worldwide economic conditions and the condition of the oil and natural gas industry.
Recent economic data indicates the rate of economic growth worldwide has declined significantly form the growth rates experienced in recent years. Current economic conditions have resulted in uncertainty regarding energy and commodity prices. In addition, future economic conditions may cause many oil and natural gas production companies to further reduce or delay expenditures in order to reduce costs, which in turn may cause a further reduction in the demand for drilling services. If conditions worsen, our business and financial condition may be adversely impacted.
Our business involves numerous operating hazards, and our insurance and contractual indemnity rights may not be adequate to cover our losses.
Our operations are subject to the usual hazards inherent in the drilling and operation of oil and natural gas wells, such as blowouts, reservoir damage, loss of production, loss of well control, punch throughs, craterings, fires and pollution. The occurrence of these events could result in the suspension of drilling or production operations, claims by the operator and others affected by such events, severe damage to, or destruction of, the property and equipment involved, injury or death to drilling personnel, environmental damage and increased insurance costs. We may also be subject to personal injury and other claims of drilling personnel as a result of our drilling operations. Operations also may be suspended because of machinery breakdowns, abnormal operating conditions, failure of subcontractors to perform or supply goods or services and personnel shortages.
Damage to the environment could result from our operations, particularly through oil spillage or extensive uncontrolled fires. We may also be subject to property, environmental and other damage claims by host governments, oil and natural gas companies and other businesses operating offshore and in coastal areas, as well as claims by individuals living in or around coastal areas.
As is customary in our industry, the risks of our operations are partially covered by our insurance and partially by contractual indemnities from our customers. However, insurance policies and contractual rights to indemnity may not adequately cover losses, and we may not have insurance coverage or rights to indemnity for all risks. Moreover, pollution and environmental risks generally are not fully insurable. If a significant accident or other event resulting in damage to our drilling units, including severe weather, terrorist acts, war, civil disturbances, pollution or environmental damage, occurs and is not fully covered by insurance or a recoverable indemnity from a customer, it could adversely affect our financial condition and results of operations.
Our business is subject to numerous governmental laws and regulations, including those that may impose significant costs and liability on us for environmental and natural resource damages.
Many aspects of our operations are affected by governmental laws and regulations that may relate directly or indirectly to the contract drilling industry, including those requiring us to control the discharge of oil and other contaminants into the environment or otherwise relating to environmental protection. Countries where we currently operate have environmental laws and regulations covering the discharge of oil and other contaminants and protection of the environment in connection with operations. Additionally, our operations and activities in the United States and its territorial waters are subject to numerous environmental laws and regulations, including the Clean Water Act, the OPA, the Outer Continental Shelf Lands Act, the Comprehensive Environmental Response, Compensation and Liability Act, the Clean Air Act, the Resource Conservation and Recovery Act and MARPOL. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, the imposition of remedial obligations, the denial or revocation of permits or other authorizations and the issuance of injunctions that may limit or prohibit our operations.
Laws and regulations protecting the environment have become more stringent in recent years and may in certain circumstances impose strict liability, rendering us liable for environmental and natural resource damages without regard to negligence or fault on our part. These laws and regulations may expose us to liability for the conduct of, or conditions caused by, others or for acts that were in compliance with all applicable laws at the time the acts were performed. The application of these requirements, the modification of existing laws or regulations or the adoption of new laws or regulations relating to exploratory or development drilling for oil and natural gas could materially limit future contract drilling opportunities or materially increase our costs. In addition, we may be required to make significant capital expenditures to comply with such laws and regulations.
In addition, some financial institutions are imposing, as a condition to financing, requirements to comply with additional non-governmental environmental and social standards in connection with operations outside the United States, such as the Equator Principles, a credit risk management framework for determining, assessing and managing environmental and social risk in project finance transactions. Such additional standards could impose significant new costs on us, which may materially and adversely affect us.
Changes in U.S. federal laws and regulations, or in those of other jurisdictions where we operate, including those that may impose significant costs and liability on us for environmental and natural resource damages, may adversely affect our operations.
If the U.S. government amends or enacts new federal laws or regulations, our potential exposure to liability for operations and activities in the United States and its territorial waters may increase. Although the Oil Pollution Act of 1990 provides federal caps on liability for pollution or contamination, future laws and regulations may increase our liability for pollution or contamination resulting from any operations and activities that the Company may have in the United States and its territorial waters including punitive damages and administrative, civil and criminal penalties. Additionally, other jurisdictions where we operate have modified, or may in the future modify, their laws and regulations in a manner that would increase our liability for pollution and other environmental damage.
Our financial condition may be adversely affected if we are unable to identify and complete future acquisitions, fail to successfully integrate acquired assets or businesses we acquire, or are unable to obtain financing for acquisitions on acceptable terms.
The acquisition of assets or businesses that we believe to be complementary to our exploration and production operations is an important component of our business strategy. We believe that acquisition opportunities for EnerJex, such as the merger with Black Raven, may arise from time to time, and that any such acquisition could be significant. At any given time, discussions with one or more potential sellers may be at different stages. However, any such discussions may not result in the consummation of an acquisition transaction, and we may not be able to identify or complete any acquisitions. We cannot predict the effect, if any, that any announcement or consummation of an acquisition would have on the trading price of our securities. Our business is capital intensive and any such transactions could involve the payment by us of a substantial amount of cash. We may need to raise additional capital through public or private debt or equity financings to execute our growth strategy and to fund acquisitions. Adequate sources of capital may not be available when needed on favorable terms. If we raise additional capital by issuing additional equity securities, existing stockholders may be diluted. If our capital resources are insufficient at any time in the future, we may be unable to fund acquisitions, take advantage of business opportunities or respond to competitive pressures, any of which could harm our business.
Any future acquisitions could present a number of risks, including:
| · | the risk of using management time and resources to pursue acquisitions that are not successfully completed; |
| · | the risk of incorrect assumptions regarding the future results of acquired operations; |
| · | the risk of failing to integrate the operations or management of any acquired operations or assets successfully and timely; and |
| · | the risk of diversion of management's attention from existing operations or other priorities. |
If we are unsuccessful in completing acquisitions of other operations or assets, our financial condition could be adversely affected and we may be unable to implement an important component of our business strategy successfully. In addition, if we are unsuccessful in integrating our acquisitions in a timely and cost-effective manner, our financial condition and results of operations could be adversely affected.
The loss of some of our key executive officers and employees could negatively impact our business prospects.
Our future operational performance depends to a significant degree upon the continued service of key members of our management as well as marketing, sales and operations personnel. The loss of one or more of our key personnel could have a material adverse effect on our business. We believe our future success will also depend in large part upon our ability to attract, retain and further motivate highly skilled management, marketing, sales and operations personnel. We may experience intense competition for personnel, and we cannot assure you that we will be able to retain key employees or that we will be successful in attracting, assimilating and retaining personnel in the future.
Failure to employ a sufficient number of skilled workers or an increase in labor costs could hurt our operations.
We require skilled personnel to operate and provide technical services to, and support for, our drilling units. In periods of increasing activity and when the number of operating units in our areas of operation increases, either because of new construction, re-activation of idle units or the mobilization of units into the region, shortages of qualified personnel could arise, creating upward pressure on wages and difficulty in staffing. The shortages of qualified personnel or the inability to obtain and retain qualified personnel also could negatively affect the quality and timeliness of our work. In addition, our ability to expand operations depends in part upon our ability to increase the size of the skilled labor force.
Risks Related to EnerJex
We have sustained losses which raises doubt asin the past, and our future profitability is subject to our ability to successfully develop profitable business operations.
Our prospects must be considered in light of the risks, expenses and difficulties frequently encountered in establishing and maintaining a business in the oilexploration and natural gas industries.production industry. There is nothing conclusive at this time on which to base an assumption that our business operations will prove to be successful or that we will be able to operate profitably. Our future operating results will depend on many factors, including:
| · | the future prices of |
| · | our ability to raise adequate |
| · | success of our development and exploration efforts; |
| · | our ability to manage our operations cost effectively |
| · | effects of our hedging strategies; |
| · | demand for |
| · | the level of our competition; |
| · | our ability to attract and maintain key management, employees and operators; |
| · | transportation and processing fees on our facilities; |
| · | fuel conservation measures; |
| · | alternate fuel requirements or advancements; |
| · | government regulation and taxation; |
| · | technical advances in fuel economy and energy generation devices; and |
| · | our ability to efficiently explore, develop and produce sufficient quantities of marketable |
To achieve profitable operations, we must, alone or with others, successfully execute on the factors stated above, along with continually developing ways to enhance our production efforts. Despite our best efforts, we may not be successful in our development efforts or obtain required regulatory approvals. There is a possibility that some of our wells may never produce natural gas or oil in sustainable or economic quantities
We will need additional capital in the future to finance our planned growth, which we may not be able to raise or may only be available on terms unfavorable to us or our stockholders, which may result in our inability to fund our working capital requirements and harm our operational results.
We have and expect to continue to have substantial capital expenditure and working capital needs. We will need to rely on cash flow from operations and borrowings under our Credit Facilitycredit facility or raise additional cash to fund our operations, pay outstanding long-term debt, fund our anticipated reserve replacement needs and implement our growth strategy, or respond to competitive pressures and/or perceived opportunities, such as investment, acquisition, exploration, work-over and development activities.
If low natural gas and oil prices, operating difficulties, constrained capital sources or other factors, many of which are beyond our control, cause our revenues or cash flows from operations to decrease, we may be limited in our ability to spend the capital necessary to complete our development, production exploitation and exploration programs. If our resources or cash flows do not satisfy our operational needs, we will require additional financing, in addition to anticipated cash generated from our operations, to fund our planned growth. Additional financing might not be available on terms favorable to us, or at all. If adequate funds were not available or were not available on acceptable terms, our ability to fund our operations, take advantage of opportunities, develop or enhance our business or otherwise respond to competitive pressures would be significantly limited. In such a capital restricted situation, we may curtail our acquisition, drilling, development, and exploration activities or be forced to sell some of our assets on an untimely or unfavorable basis. Our current plans to address lowera drop in crude and natural gasoil prices are primarilyto maintain hedges covering a portion of our expected future oil production and to reduce both capital and operating expenditures to a level equal to or below cash flow from operations. However, our plans may not be successful in improving our results of operations and liquidity.
If we raise additional funds through the issuance of equity or convertible debt securities, the percentage ownership of our stockholders would be reduced, and these newly issued securities might have rights, preferences or privileges senior to those of existing stockholders,
Approximately 68%47% of our total proved reserves as of MarchDecember 31, 20092012 consist of undeveloped and developed non-producing reserves, and those reserves may not ultimately be developed or produced.
Our estimated total proved PV 10PV10 (present value) before tax of reserves as of MarchDecember 31, 20092012 was $10.63$60.8 million, versus $39.6$53.2 million as of MarchDecember 31, 2008. The decline in PV10 is primarily due to2011. Of the estimated average price2.9 million net barrels of oil at MarchDecember 31, 2009 of $42.65 versus $94.53 at March 31, 2008. We held total proved reserves of 1.3 million barrels of oil equivalent, or BOE, as of March 31, 2009. Of the 1.3 million BOE of total proved reserves,2012, approximately 39%53% are proved developed producing, and approximately 61%47% are proved undeveloped. The proved developed reserves consist of 82% proved developed producing reserves and 18% proved developed non-producing reserves. See “Glossary” on 77 for our definition of PV10.
Assuming we can obtain adequate capital resources, we plan to develop and produce all of our proved reserves, but ultimately some of these reserves may not be developed or produced. Furthermore, not all of our undeveloped or developed non-producing reserves may be ultimately produced in the time periods we have planned, at the costs we have budgeted, or at all.
Because we face uncertainties in estimating provenproved recoverable reserves, you should not place undue reliance on such reserve information.
Our reserve estimateestimates and the future net cash flows attributable to those reserves at MarchDecember 31, 2009 was2012 were prepared by Miller and Lents, Ltd.,MHA Petroleum Consultants LLC, an independent petroleum consultant. Prior to this fiscal year, our reserves were evaluated and estimates were prepared by McCune Engineering, an independent petroleum and geological engineer. There are numerous uncertainties inherent in estimating quantities of proved reserves and cash flows from such reserves, including factors beyond our control and the control of these independent consultants and engineers. Reserve engineering is a subjective process of estimating underground accumulations of natural gas and oil that can be economically extracted, which cannot be measured in an exact manner. The accuracy of an estimate of quantities of reserves, or of cash flows attributable to these reserves, is a function of the available data, assumptions regarding future natural gas and oil prices, expenditures for future development and exploitation activities, and engineering and geological interpretation and judgment. Reserves and future cash flows may also be subject to material downward or upward revisions based upon production history, development and exploitation activities and natural gas and oil prices. Actual future production, revenue, taxes, development expenditures, operating expenses, quantities of recoverable reserves and value of cash flows from those reserves may vary significantly from the assumptions and estimates in our reserve reports. Any significant variance from these assumptions to actual figures could greatly affect our estimates of reserves, the economically recoverable quantities of natural gas and oil attributable to any particular group of properties, the classification of reserves based on risk of recovery, and estimates of the future net cash flows. In addition, reserve engineers may make different estimates of reserves and cash flows based on the same available data. The estimated quantities of proved reserves and the discounted present value of future net cash flows attributable to those reserves included in this report were prepared by Miller and Lents, Ltd.MHA Petroleum Consultants LLC in accordance with rules of the Securities and Exchange Commission, or SEC, and are not intended to represent the fair market value of such reserves.
The present value of future net cash flows from our proved reserves is not necessarily the same as the current market value of our estimated reserves. We base the estimated discounted future net cash flows from our proved reserves on prices and costs. However, actual future net cash flows from our natural gas and oil properties also will be affected by factors such as:
| · | geological conditions; |
| · | assumptions governing future oil |
| · | amount and timing of actual production; |
| · | availability of funds; |
| · | future operating and development costs; |
| · | actual prices we receive for |
| · | changes in government regulations and taxation; and |
| · | capital costs of drilling new wells. |
The timing of both our production and our incurrence of expenses in connection with the development and production of our properties will affect the timing of actual future net cash flows from proved reserves, and thus their actual present value. In addition, the 10% discount factor we use when calculating discounted future net cash flows may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with our business or the natural gas and oil industry in general.
The differential between the New York Mercantile Exchange, or NYMEX, or other benchmark price of oil and natural gas and the wellhead price we receive could have a material adverse effect on our results of operations, financial condition and cash flows.
The prices that we receive for our oil production in Eastern Kansas and natural gas productionEastern Colorado are typically trade atbased on a discount to the relevant benchmark prices, such as NYMEX, that are used for calculating hedge positions. In South Texas, the prices that we receive for our oil production are currently based on a premium to NYMEX. The difference between the benchmark price and the price we receive is called a differential. While we have fixed this differential under the terms of our agreement with Coffeyville Resources Refining and Marketing, LLC (“Coffeyville”) through March 31, 2011 and may continue on a month to month basis after that date, weWe cannot accurately predict future oil and natural gas differentials. In recent years for example, production increases from competing Canadian and Rocky Mountain producers, in conjunction with limited refining and pipeline capacity from the Rocky Mountain area, have gradually widened this differential. Recent economic conditions, including volatility in the price of oil, and natural gas, have resulted in both increases and decreases in the differential between the benchmark price for oil and natural gas and the wellhead price we receive. These fluctuations could have a material adverse effect on our results of operations, financial condition and cash flows by decreasing the proceeds we receive for our oil and natural gas production in comparison to what we would receive if not for the differential
In order to exploit successfully our current oil leases and oil business involves numerous uncertainties and operating risksothers that can prevent us from realizing profits and can cause substantial losses.
The oil well does not ensure a profit on investment. Exploratory wells bear a much greater risk of loss thanexploration, development wells. Substantially all of our wells drilled through October 31, 2009 have been development wells. A variety of factors, both geological and market-related, can cause a well to become uneconomical or only marginally economic. Our initial drilling and development sites, and any potential additional sites that may be developed, require significant additional exploration and development, regulatory approval and commitments of resources prior to commercial development. If our actual drilling and development costs are significantly more than our estimated costs, we may not be able to continue our business operations as proposed and would be forced to modify our plan of operation.
A significant portion of our potential future reserves and our business plan depend upon secondary recovery techniques to establish production. There are significant risks associated with such techniques.
We anticipate that a significant portion of our future reserves and our business plan will be associated with secondary recovery projects that are either in the early stage of implementation or are scheduled for implementation.implementation subject to availability of capital. We anticipate that secondary recovery will affect our reserves and our business plan, and the exact project initiation dates and, by the very nature of waterflood operations, the exact completion dates of such projects are uncertain. In addition, the reserves and our business plan associated with these secondary recovery projects, as with any reserves, are estimates only, as the success of any development project, including these waterflood projects, cannot be ascertained in advance. If we are not successful in developing a significant portion of our reserves associated with secondary recovery methods, then the project may be uneconomic or generate less cash flow and reserves than we had estimated prior to investing the capital. Risks associated with secondary recovery techniques include, but are not limited to, the following:
| · | higher than projected operating costs; |
| · | lower-than-expected production; |
| · | longer response times; |
| · | higher costs associated with obtaining capital; |
| · | unusual or unexpected geological formations; |
| · | fluctuations in |
| · | regulatory changes; |
| · | shortages of equipment; and |
| · | lack of technical expertise. |
If any of these risks occur, it could adversely affect our financial condition or results of operations.
Any acquisitions we complete are subject to considerable risk.
Even when we make acquisitions that we believe are good for our business, any acquisition involves potential risks, including, among other things:
| · | the validity of our assumptions about reserves, future production, revenues and costs, including synergies; |
| · | an inability to integrate successfully the businesses we acquire; |
| · | a decrease in our liquidity by using our available cash or borrowing capacity to finance acquisitions; |
| · | a significant increase in our interest expense or financial leverage if we incur additional debt to finance acquisitions; |
| · | the assumption of unknown liabilities, losses or costs for which we are not indemnified or for which our indemnity is inadequate; |
| · | the diversion of |
| · | an inability to hire, train or retain qualified personnel to manage the acquired properties or assets; |
| · | the incurrence of other significant charges, such as impairment of goodwill or other intangible assets, asset devaluation or restructuring charges; |
| · | unforeseen difficulties encountered in operating in new geographic or geological areas; and |
| · | customer or key employee losses at the acquired businesses. |
Due to our lack of geographic diversification, adverse developments in our operating areas would materially affect our business.
We currently only lease and operate oil and natural gas properties located in Eastern Kansas.Kansas, Eastern Colorado, and South Texas. As a result of this concentration, we may be disproportionately exposed to the impact of delays or interruptions of production from these properties caused by significant governmental regulation, transportation capacity constraints, curtailment of production, natural disasters, adverse weather conditions or other events which impact this area.
We depend on a small number of customers for all, or a substantial amount of our sales. If these customers reduce the volumes of oil and natural gas they purchase from us, our revenue and cash available for distribution will decline to the extent we are not able to find new customers for our production.
We have contracted withcurrently sell oil to two purchasers in Eastern Kansas: Coffeyville for the saleResources and Plains Marketing. There are approximately five potential purchasers of all of our oil through March 2011in Eastern Kansas, and will likely contract for the sale of our natural gas with one, or a small number, of buyers if and when we resume operations on the Gas City Project. Itit is not likely that there will be a large pool of available purchasers. If a key purchaser were to reduce the volume of oil or natural gas it purchases from us, our revenue and cash available for operations will decline to the extent we are not able to find new customers to purchase our production at equivalent prices
We currently sell oil to Plains Marketing in Eastern Colorado and Sunoco in South Texas. The number of purchasers in these areas is numerous, but increased production volumes from extensive unconventional resource shale drilling activity in the area may result in bottlenecks with various purchasers.
We are not the operator of some of our properties and we have limited control over the activities on those properties.
We are not the operator onof our Black Oaks Project. We have only limited ability to influence or control the operation or future development of the Black OaksMississippian Project, or the amount of capital expenditures that we can fund with respect to it. In the case of the Black Oaks Project,and our dependence on the operator Haas Petroleum,of this project limits our ability to influence or control the operation or future development of thethis project. Such limitations could materially adversely affect the realization of our targeted returns on capital related to exploration, drilling or production activities and lead to unexpected future costs.
We may suffer losses or incur liability for events for which we or the operator of a property have chosen not to obtain insurance.
Our operations are subject to hazards and risks inherent in producing and transporting natural gas and oil, such as fires, natural disasters, explosions, pipeline ruptures, spills, and acts of terrorism, all of which can result in the loss of hydrocarbons, environmental pollution, personal injury claims and other damage to our and others’others' properties. As protection against operating hazards, we maintain insurance coverage against some, but not all, potential losses. In addition, pollution and environmental risks generally are not fully insurable. As a result of market conditions, existing insurance policies may not be renewed and other desirable insurance may not be available on commercially reasonable terms, if at all. The occurrence of an event that is not covered, or not fully covered, by insurance could have a material adverse effect on our business, financial condition and results of operations.
Our hedging activities could result in financial losses or could reduce our available funds or income and therefore adversely affect our financial position.
To achieve more predictable cash flow and to reduce our exposure to adverse fluctuations in the prices of oil, and natural gas, we have entered into derivative arrangements from April 1, 2008 until December 31, 2013through for betweenvolumes of approximately 30 and 165350 barrels of oil per day in 2014 and 320 barrels of oil per day in 2015 that could result in both realized and unrealized hedging losses. As of September 30, 2009December 31, 2012, we had not incurred any such losses.realized and unrealized gains of approximately $56,000. The extent of our commodity price exposure is related largely to the effectiveness and scope of our derivative activities. For example, the derivative instruments we may utilize may be based on posted market prices, which may differ significantly from the actual crude oil natural gas and NGL prices we realize in our operations.
Our actual future production may be significantly higher or lower than we estimate at the time we enter into derivative transactions for such period. If the actual amount is higher than we estimate, we will have greater commodity price exposure than we intended. If the actual amount is lower than the nominal amount that is subject to our derivative financial instruments, we might be forced to satisfy all or a portion of our derivative transactions without the benefit of the cash flow from our sale or purchase of the underlying physical commodity, resulting in a substantial diminution of our liquidity. As a result of these factors, our derivative activities may not be as effective as we intend in reducing the volatility of our cash flows, and in certain circumstances may actually increase the volatility of our cash flows. In addition, while we believe our existing derivative activities are with creditworthy counterparties, (Coffeyville and BP), continued deterioration in the credit markets may cause a counterparty not to perform its obligation under the applicable derivative instrument or impact their willingness to enter into future transactions with us.
Our business depends in part on gathering and transportationprocessing facilities owned by others. Any limitation in the availability of those facilities could interfere with our ability to market our oil and natural gas production and could harm our business.
The marketability of our oil and natural gas production will depend in a very large part on the availability, proximity and capacity of pipelines oil and natural gas gathering systems andoil processing facilities. The amount of oil and natural gas that can be produced and sold is subject to curtailment in certain circumstances, such as pipeline interruptions due to scheduled and unscheduled maintenance, excessive pressure, physical damage or lack of available capacity on such systems. The curtailments arising from these and similar circumstances may last from a few days to several months. In many cases, we will be provided only with limited, if any, notice as to when these circumstances will arise and their duration. Any significant curtailment in gathering systempipeline capacity or pipelinethe capacity of processing facilities could significantly reduce our ability to market our oil and natural gas production and could materially harm our business.
Our reserves are subject to the risk of depletion because many of our leases are in mature fields that have produced large quantities of oil and natural gas to date.
A significant portion of our operations are located in or near established fields in Eastern Kansas.Kansas and South Texas. As a result, many of our leases are in, or directly offset, areas that have produced large quantities of oil and natural gas to date. As such, our reserves may be partially or completely depletednegatively impacted by offsetting wells or previously drilled wells, which could significantly harm our business
Our lease ownership may be diluted due to financing strategies we may employ in the future due to our lack of capital.
To accelerate our development efforts, we may take on working interest partners who will contribute to the costs of drilling and completion operations and then share in revenuesany cash flow derived from production. In addition, we may in the future, due to a lack of capital or other strategic reasons, establish joint venture partnerships or farm out all or part of our development efforts. These economic strategies may have a dilutive effect on our lease ownership and could significantly reduce our operating revenues.
We may face lease expirations on leases that are not currently held-by-production.
We have numerous leases that are not currently held-by-production, some of which have near term lease expirations and are likely to expire. Although we believe that we can maintain our most desirable leases by conducting drilling operations or by negotiating lease extensions, we can make no guarantee that we can maintain these leases.
We are subject to complex laws and regulations, including environmental regulations, which can adversely affect the cost, manner or feasibility of doing business.
Development, production and sale of natural gas and oil in the United States are subject to extensive laws and regulations, including environmental laws and regulations. We may be required to make large expenditures to comply with environmental and other governmental regulations. Matters subject to regulation include, but are not limited to:
| · | location and density of wells; |
| · | the handling of drilling fluids and obtaining discharge permits for drilling operations; |
| · | accounting for and payment of royalties on production from state, federal and Indian lands; |
| · | bonds for ownership, development and production of |
| · | transportation of |
| · | operation of wells and reports concerning operations; and |
| · | taxation. |
Under these laws and regulations, we could be liable for personal injuries, property damage, oil spills, discharge of hazardous materials, remediation and clean-up costs and other environmental damages. Failure to comply with these laws and regulations also may result in the suspension or termination of our operations and subject us to administrative, civil and criminal penalties. Moreover, these laws and regulations could change in ways that substantially increase our costs. Accordingly, any of these liabilities, penalties, suspensions, terminations or regulatory changes could materially adversely affect our financial condition and results of operations enough to possibly force us to cease our business operations.
Our operations may expose us to significant costs and liabilities with respect to environmental, operational safety and other matters.
We may incur significant costs and liabilities as a result of environmental and safety requirements applicable to our oil and natural gas exploration and production activities. We may also be exposed to the risk of costs associated with Kansas Corporation Commission and /or the Texas Railroad Commission, Colorado Oil and Gas Conservation Commission, requirements to plug orphaned and abandoned wells on our oil and natural gas leases from wells previously drilled by third parties. In addition, we may indemnify sellers or lessors of oil and natural gas properties for environmental liabilities they or their predecessors may have created. These costs and liabilities could arise under a wide range of federal, state and local environmental and safety laws and regulations, including regulations and enforcement policies, which have tended to become increasingly strict over time. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, imposition of cleanup and site restoration costs, liens and to a lesser extent, issuance of injunctions to limit or cease operations. In addition, claims for damages to persons or property may result from environmental and other impacts of our operations.
Strict, joint and several liability may be imposed under certain environmental laws, which could cause us to become liable for the conduct of others or for consequences of our own actions that were in compliance with all applicable laws at the time those actions were taken. New laws, regulations or enforcement policies could be more stringent and impose unforeseen liabilities or significantly increase compliance costs. If we are not able to recover the resulting costs through insurance or increased revenues, our ability to operate effectively could be adversely affected.
We may incur substantial write-downs of the carrying value of our natural gas and oil properties, which would adversely impact our earnings.
We review the carrying value of our natural gas and oil properties under the full-cost accounting rules of the SEC on a quarterly basis. This quarterly review is referred to as a ceiling test. Under the ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes, may not exceed an amount equal to the sum of the present value of estimated future net revenues (adjusted for cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. In calculating future net revenues, current prices and costs used are those as of the end of the appropriate quarterly period. Such prices are utilized except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts, including the effects of derivatives qualifying as cash flow hedges. Two primary factors impacting this test are reserve levels and current prices, and their associated impact on the present value of estimated future net revenues. Revisions to estimates of natural gas and oil reserves and/or an increase or decrease in prices can have a material impact on the present value of estimated future net revenues. Any excess of the net book value, less deferred income taxes, is generally written off as an expense. Under SEC regulations, the excess above the ceiling is not expensed (or is reduced) if, subsequent to the end of the period, but prior to the release of the financial statements, natural gas and oil prices increase sufficiently such that an excess above the ceiling would have been eliminated (or reduced) if the increased prices were used in the calculations.
In December 2008, the SEC issued new regulations for oil and gas reserve reporting which go into effectwere effective for fiscal years ending on or after December 31, 2009. One of the key elements of the new regulations relate to the commodity prices which are used to calculate reserves and their present value. The new regulations provide for disclosure of oil and gas reserves evaluated using annual average prices based on the prices in effect on the first day of each month rather than the current regulations which utilize commodity prices on the last day of the year.
There was no impairment for the fiscal year ended MarchDecember 31, 2008. We recorded an impairment of $4,777,723 during2012, or for the fiscal year ended March 31, 2009
Failure to execute our business plan.
Section 404 of the articlesSarbanes-Oxley Act of incorporation2002 requires our management to assess the effectiveness of its internal control over financial reporting and bylaws could also make it more difficultto provide a report by its registered independent public accounting firm addressing the effectiveness of our internal control over financial reporting. The Committee of Sponsoring Organizations of the Treadway Commission (COSO) provides a framework for a third partycompanies to acquireassess and improve their internal control of us. In addition, Nevada’s “
A small number of customers account for a significant portion of our shares.
We derive a significant portion of our revenues from a few customers. During the fiscal year ended December 31, 2012, our four largest customers accounted for approximately 44%, 24%, 11% and 10%, respectively, of our revenue. Our financial condition and results of operations could be materially and adversely affected if any one of these customers interrupts or curtails their activities, fail to pay for the services that have been performed, terminate their contracts, fail to renew their existing contracts or refuse to award new contracts and we are unable to enter into contracts with new customers on comparable terms. The loss of any of our significant customers could materially adversely affect our financial condition and results of operations.
We are exposed to the credit risks of our key customers, including certain affiliated companies, and certain other third parties, and nonpayment by these customers and other parties could adversely affect our financial position, results of operations and cash flows.
We are subject to risks of loss resulting from nonpayment or nonperformance by our customers. Any material nonpayment or nonperformance by key customers and certain other third parties could adversely affect our financial position, results of operations and cash flows. If any key customers or other parties default on their obligations to us, our financial results and condition could be adversely affected. Furthermore, some of these customers and other parties may be highly leveraged and subject to their own operating and regulatory risks.
Our operations might be interrupted by the occurrence of a natural disaster or other catastrophic event.
Our principal executive office is in San Antonio, Texas. Natural disasters or other catastrophic events could disrupt our operations or those of its strategic partners, contractors and vendors. Even though we believe we carries commercially reasonable business interruption and liability insurance, and its contractors may carry liability insurance that protect us in certain events, we might suffer losses as a result of business interruptions that exceed the coverage available under its and its contractors' insurance policies or for which it or its contractors do not have coverage. Any natural disaster or catastrophic event could have a significant negative impact on our operations and financial results, and could delay its efforts to identify and execute any strategic opportunities.
SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS
This prospectus contains “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act. All statements in this prospectus, other than statements of historical facts, which address activities, events or developments that we expect or anticipate will or may occur in the future, including such things as future capital expenditures, growth, product development, sales, business strategy and other similar matters are forward-looking statements. You can identify forward-looking statements by terminology such as “may,” “will,” “would,” “could,” “should,” “expect,” “intend,” “plan,” “anticipate,” “believe,” “estimate,” “predict,” “potential,” “continue” or the negative of these terms or other similar expressions or phrases. These forward-looking statements are based largely on our current expectations and assumptions and are subject to a number of risks and uncertainties, many of which are beyond our control. AllActual results could differ materially from the forward-looking statements other than statementsset forth herein as a result of historical fact, containeda number of factors, including, but not limited to, our products’ current state of development, the need for additional financing, changes in this prospectus, including statements regarding future events, our future financial performance, business strategy, and plans and objectivescompetition in various aspects of management for future operations, are forward-looking statements. We have attempted to identify forward-looking statements by terminology including “anticipates,” “believes,” “can,” “continue,” “could,” “estimates,” “expects,” “intends,” “may,” “plans,” “potential,” “predicts” or & #8220;should” or the negative of these terms or other comparable terminology. Although we do not make forward-looking statements unless we believe we have a reasonable basis for doing so, we cannot guarantee their accuracy. These statements are only predictions and involve known and unknown risks, uncertainties and other factors, includingour business, the risks outlineddescribed under “Risk Factors” or elsewhere inbeginning on page[·] of this prospectus which may causeand other risks detailed in our or our industry’s actual results, levels of activity, performance or achievements to be materially different from any future results, levels of activity, performance or achievements expressed or implied by these forward-looking statements. Moreover, we operate in a very competitivereports filed with the Securities and rapidly changing environment. New risks emerge from time to time and it is not possible for us to predict all risk factors, nor can we address the impact of all factors on our businessExchange Commission, or the extent to which any factor, or combinationSEC. In light of factors, may cause our actual results to differ materially from those contained in any forward-looking statements. The factors impacting these risks and uncertainties, include, but are not limited to:
MATERIAL U.S. FEDERAL INCOME TAX CONSEQUENCES
Subject to the assumptions, qualifications, and limitations set forth below, the following is the opinion of Reicker, Pfau, Pyle & McRoy LLP, counsel to EnerJex, with respect to the material U.S. federal income tax consequences to “U.S. holders” and “Non-U.S. holders” (each as defined below) of the purchase, ownership and disposition of Series B Preferred Stock offered by the selling stockholders under this prospectus. Counsel’s opinions are limited to statements of U.S. federal income tax law and regulations and legal conclusions with respect thereto.
This discussion is based upon provisions of the Internal Revenue Code of 1986, as amended (the “Code”), Treasury regulations, rulings and judicial decisions as of the date hereof. These authorities may change, perhaps retroactively, which could result in U.S. federal income tax consequences different from those summarized below. This discussion only applies to purchasers who purchase and hold the Series A Preferred Stock as capital assets within the meaning of Section 1221 of the Code (generally property held for investment). This discussion does not address all aspects of U.S. federal income taxation (such as the alternative minimum tax) and does not describe any foreign, state, local or other tax considerations that may be relevant to a purchaser or holder of Series B Preferred Stock in light of their particular circumstances. In addition, this discussion does not describe the U.S. federal income tax consequences applicable to a purchaser or holder of Series B Preferred Stock who is subject to special treatment under U.S. federal income tax laws (including, a corporation that accumulates earnings to avoid U.S. federal income tax, a pass-through entity or an investor in a pass-through entity, a tax-exempt entity, pension or other employee benefit plans, financial institutions or broker-dealers, persons holding Series B Preferred Stock as part of a hedging or conversion transaction or straddle, a person subject to the alternative minimum tax, an insurance company, former U.S. citizens, or former long-term U.S. residents). We cannot assure you that a change in law will not significantly alter the tax considerations that we describe in this discussion. Counsel’s opinions are an expression of professional judgment and are not a guarantee of a result and are not binding on the Internal Revenue Service or the courts. Accordingly, no assurance can be given that counsel’s opinions set forth herein will be sustained if challenged by the Internal Revenue Service.
If a partnership (or any other entity treated as a partnership for U.S. federal income tax purposes) holds Series B Preferred Stock, the U.S. federal income tax treatment of a partner of that partnership generally will depend upon the status of the partner and the activities of the partnership. If you are a partnership or a partner of a partnership holding our Series B Preferred Stock, you should consult your tax advisors as to the particular U.S. federal income tax consequences of holding and disposing of our Series B Preferred Stock.
THIS DISCUSSION CANNOT BE USED BY ANY HOLDER FOR THE PURPOSE OF AVOIDING TAX PENALTIES THAT MAY BE IMPOSED ON SUCH HOLDER. IF YOU ARE CONSIDERING THE PURCHASE OF OUR SERIES B PREFERRED STOCK, YOU SHOULD CONSULT YOUR OWN TAX ADVISORS CONCERNING THE U.S. FEDERAL INCOME TAX CONSEQUENCES OF PURCHASING, OWNING AND DISPOSING OF OUR SERIES B PREFERRED STOCK IN LIGHT OF YOUR PARTICULAR CIRCUMSTANCES AND ANY CONSEQUENCES ARISING UNDER OTHER FEDERAL TAX LAW AND THE LAWS OF APPLICABLE STATE, LOCAL AND FOREIGN TAXING JURISDICTIONS. YOU SHOULD ALSO CONSULT WITH YOUR TAX ADVISORS CONCERNING ANY POSSIBLE ENACTMENT OF LEGISLATION THAT WOULD AFFECT YOUR INVESTMENT IN OUR SERIES B PREFERRED STOCK IN YOUR PARTICULAR CIRCUMSTANCES.
U.S. holders:
You are a “U.S. holder” if you are a beneficial owner of Series B Preferred stock and you are for U.S. federal income tax purposes:
| • | an individual citizen or resident of the United States; | ||
| • | a corporation (or other entity treated as a corporation for U.S. federal income tax purposes) created or organized in or under the laws of the United States, any state thereof or the District of Columbia; | ||
| • | an estate, the income of which is subject to U.S. federal income taxation regardless of its source; or | ||
| • | a trust if it (a) is subject to the primary supervision of a court within the United States and one or more United States persons have the authority to control all substantial decisions of the trust or (b) has a valid election in effect under applicable United States Treasury regulations to be treated as a United States person. | ||
Distributions in General. If distributions are made with respect to our Series B Preferred Stock, such distributions will be treated as dividends to the extent of our current and accumulated earnings and profits as determined under the Code. Any portion of a distribution that exceeds our current and accumulated earnings and profits will first be applied to reduce a U.S. holder’s tax basis in the Series B Preferred Stock on a share-by-share basis, and the excess will be treated as gain from the disposition of the Series B Preferred Stock, the tax treatment of which is discussed below under “Material U.S. Federal Income Tax Consequences—U.S. holders: Disposition of Series B Preferred Stock, Including Redemptions.”
Dividends received by individual U.S. holders of Series B Preferred Stock will be subject to a reduced maximum tax rate of 20% if such dividends are treated as “qualified dividend income” for U.S. federal income tax purposes. The rate reduction does not apply to dividends received to the extent that the individual U.S. holder elects to treat the dividends as “investment income,” which may be offset against investment expenses. Furthermore, the rate reduction does not apply to dividends that are paid to individual U.S. holders with respect to the Series B Preferred Stock that is held for 60 days or less during the 121-day period beginning on the date which is 60 days before the date on which the Series B Preferred Stock becomes ex-dividend. Also, if a dividend received by an individual U.S. holder that qualifies for the rate reduction is an “extraordinary dividend” within the meaning of Section 1059 of the Code, any loss recognized by such individual U.S. holder on a subsequent disposition of the stock will be treated as long-term capital loss to the extent of such “extraordinary dividend,” irrespective of such U.S. holder’s holding period for the stock. In addition, under the Patient Protection and 2010 Reconciliation Act (the “2010 Reconciliation Act”), dividends recognized after December 31, 2013, by U.S. holders that are individuals could be subject to the 3.8% tax on net investment income. Individual U.S. holders should consult their own tax advisors regarding the implications of these rules in light of their particular circumstances.
Dividends received by corporations generally will be eligible for the dividends-received deduction. This deduction is allowed if the underlying stock is held for at least days during the 91 day period beginning on the date 45 days before the ex-dividend date of the stock, and for cumulative preferred stock with an arrearage of dividends, the holding period is at least 91 days during the 181 day period beginning on the date 90 days before the ex-dividend date of the stock. If a corporate stockholder receives a dividend on the Series B Preferred Stock that is an “extraordinary dividend” within the meaning of Section 1059 of the Code, the corporate stockholder in certain instances must reduce its basis in the Series B Preferred Stock by the amount of the “nontaxed portion” of such “extraordinary dividend” that results from the application of the dividends-received deduction. If the “nontaxed portion” of such “extraordinary dividend” exceeds such corporate stockholder’s basis, any excess will be taxed as gain as if such stockholder had disposed of its shares in the year the “extraordinary dividend” is paid. Each domestic corporate holder of Series B Preferred Stock is urged to consult with its tax advisors with respect to the eligibility for and amount of any dividends received deduction and the application of Section 1059 of the Code to any dividends it receives.
Constructive Distributions on Series B Preferred Stock; EnerJex's Call Option. A distribution by a corporation of its stock deemed made with respect to its preferred stock is treated as a distribution of property to which Section 301 of the Code applies. If a corporation issues preferred stock that may be redeemed at a price higher than its issue price, the excess (a “redemption premium”) is treated under certain circumstances as a constructive distribution (or series of constructive distributions) of additional preferred stock.
The constructive distribution of property equal to the redemption premium would accrue without regard to the U.S. holder’s method of accounting for U.S. federal income tax purposes at a constant yield determined under principles similar to the determination of original issue discount (“OID”) under Treasury regulations under Sections 1271 through 1275 of the Code (the “OID Rules”). The constructive distributions of property would be treated for U.S. federal income tax purposes as actual distributions of Series B Preferred Stock that would constitute a dividend, return of capital or capital gain to the U.S. holder of the stock in the same manner as cash distributions described under the heading “Material U.S. Federal Income Tax Consequences—U.S. holders: Distributions in General.” The application of principles similar to those applicable to debt instruments with OID to a redemption premium for the Series B Preferred Stock is uncertain.
The Company has the right to call the Series B Preferred Stock for redemption on or after [·] (the “call option”). The stated redemption price of the Series B Preferred Stock upon the Company’s exercise of the call option is equal to the liquidation preference of the Series B Preferred Stock (i.e., $25, plus accrued and unpaid dividends) and is payable in cash.
If the redemption price of the Series B Preferred Stock exceeds the issue price of the Series B Preferred Stock upon the exercise of the call option, the excess will be treated as a redemption premium that may result in certain circumstances in a constructive distribution or series of constructive distributions to U.S. holders of additional Series B Preferred Stock. The redemption price for the Series B Preferred Stock should be the liquidation preference of the Series B Preferred Stock (i.e., $25, plus accrued and unpaid dividends). Assuming that the issue price of the Series B Preferred Stock is determined under principles similar to the OID Rules, the issue price for the Series B Preferred Stock should be the initial offering price at which a substantial amount of the Series B Preferred Stock is sold.
A redemption premium for the Series B Preferred Stock should not result in constructive distributions to U.S. holders of the Series A Preferred Stock if the redemption premium is less than a de minimis amount as determined under principles similar to the OID Rules. A redemption premium for the Series B Preferred Stock should be considered de minimis if such premium is less than [·] of the Series B Preferred Stock’s liquidation value of $25 at maturity, multiplied by the number of complete years to maturity. Because the determination under the OID Rules of a maturity date for the Series B Preferred Stock is unclear, the remainder of this prospectusdiscussion assumes that the Series B Preferred Stock is issued with a redemption premium greater than a de minimis amount.
In addition, our call option should not require constructive distributions of the redemption premium if, based on all of the facts and circumstances as of the issue date, the redemption pursuant to conformthe Company’s call option is not more likely than not to occur. The Treasury regulations provide that an issuer’s right to redeem will not be treated as more likely than not to occur if: (i) the issuer and the holder of the stock are not related within the meaning of Section 267(b) or Section 707(b) of the Code (substituting “20%” for the phrase “50%”); (ii) there are no plans, arrangements, or agreements that effectively require or are intended to compel the issuer to redeem the stock; and (iii) exercise of the right to redeem would not reduce the yield on the stock determined using principles applicable to the determination of OID under the OID rules. The fact that a redemption right is not described in the preceding sentence does not mean that an issuer’s right to redeem is more likely than not to occur and the issuer’s right to redeem must still be tested under all the facts and circumstances to determine if it is more likely than not to occur. The Company believes that its right to redeem the Series B Preferred Stock should not be treated as more likely than not to occur under the foregoing test. Accordingly, no U.S. holder of Series B Preferred Stock should be required to recognize constructive distributions of the redemption premium because of the Company’s call option.
Disposition of Series B Preferred Stock, Including Redemptions. Upon any sale, exchange, redemption (except as discussed below), or other disposition of the Series B Preferred Stock, a U.S. holder will recognize capital gain or loss equal to the difference between the amount realized by the U.S. holder and the U.S. holder’s adjusted tax basis in the Series B Preferred Stock. Such capital gain or loss will be long-term capital gain or loss if the U.S. holder’s holding period for the Series B Preferred Stock is longer than one year. A U.S. holder should consult its own tax advisors with respect to applicable tax rates and netting rules for capital gains and losses. Certain limitations exist on the deduction of capital losses by both corporate and non-corporate taxpayers. In addition, under the 2010 Reconciliation Act, gains recognized after December 31, 2013, by U.S. holders that are individuals could be subject to the 3.8% tax on net investment income.
A redemption of shares of the Series B Preferred Stock will generally be a taxable event. If the redemption is treated as a sale or exchange, instead of a dividend, a U.S. holder will recognize capital gain or loss (which will be long-term capital gain or loss, if the U.S. holder’s holding period for such Series B Preferred Stock exceeds one year), equal to the difference between the amount realized by the U.S. holder and the U.S. holder’s adjusted tax basis in the Series B Preferred Stock redeemed, except to the extent that any cash or the Company’s common stock or Series B Preferred Stock received is attributable to any accrued but unpaid dividends on the Series B Preferred Stock, which will be subject to the rules discussed above in “Material U.S. Federal Income Tax Consequences—U.S. holders: Distributions in General.” A payment made in redemption of Series B Preferred Stock may be treated as a dividend, rather than as payment in exchange for the Series B Preferred Stock, unless the redemption:
| · | is “not essentially equivalent to a dividend” with respect to a U.S. holder under Section 302(b)(1) of the Code; |
| · | is a “substantially disproportionate” redemption with respect to a U.S. holder under Section 302(b)(2) of the Code; |
| · | results in a “complete redemption” of a U.S. holder’s stock interest in the Company under Section 302(b)(3) of the Code; or |
| · | is a redemption of stock held by a non-corporate U.S. holder, which results in a partial liquidation of the Company under Section 302(b)(4) of the Code. |
In determining whether any of these tests has been met, a U.S. holder must take into account not only shares of Series B Preferred Stock and our statementscommon stock or any other stock that the U.S. holder actually owns, but also shares that the U.S. holder constructively owns within the meaning of Section 318 of the Code.
A redemption payment will be treated as “not essentially equivalent to actuala dividend” if it results or changed expectations.
Satisfaction of the “complete redemption” and “substantially disproportionate” exceptions is dependent upon compliance with the objective tests set forth in Section 302(b)(3) and Section 302(b)(2) of the Code, respectively. A redemption will result in a “complete redemption” if either all of the shares of our stock actually and constructively owned by a U.S. holder is exchanged in the redemption or all of the shares of our stock actually owned by the U.S. holder is exchanged in the redemption and the U.S. holder is eligible to waive, and the U.S. holder effectively waives, the attribution of shares of our stock constructively owned by the U.S. holder in accordance with the procedures described in Section 302(c)(2) of Code. A redemption does not qualify for the “substantially disproportionate” exception if the stock redeemed is only non-voting stock, and for this purpose, stock which does not have voting rights until the occurrence of an event is not voting stock until the occurrence of the specified event. Accordingly, any redemption of Series B Preferred Stock generally will not qualify for this exception because the voting rights are limited as provided in the “Description of Our Series B Preferred Stock—Voting Rights.”
For purposes of the “redemption from non-corporate U.S. holders in a partial liquidation” test, a distribution will be treated as in partial liquidation of a corporation if the distribution is not essentially equivalent to a dividend (determined at the corporate level rather than the stockholder level) and the distribution is pursuant to a plan and occurs within the taxable year in which the plan was adopted or within the succeeding taxable year. For these purposes, a distribution is generally not essentially equivalent to a dividend if the distribution results in a corporate contraction. The determination of what constitutes a corporate contraction is factual in nature, and had been interpreted under case law to include the termination of a business or line of business.
Each U.S. holder of Series B Preferred Stock should consult its own tax advisors to determine whether a payment made in redemption of Series B Preferred Stock will be treated as a dividend or a payment in exchange for the Series B Preferred Stock. If the redemption payment is treated as a dividend, the rules discussed above in “Material U.S. Federal Income Tax Consequences—U.S. holders: Distributions in General” apply.
Under proposed Treasury regulations, if any amount received by a U.S. holder in redemption of Series B Preferred Stock is treated as a distribution with respect to such U.S. holder’s Series B Preferred Stock, but not as a dividend, such amount will be allocated to all shares of Series B Preferred Stock held by such U.S. holder immediately before the redemption on a pro-rata basis. The amount applied to each share will reduce such U.S. holder’s adjusted tax basis in that share and any excess after the basis is reduced to zero will result in taxable gain. If such U.S. holder has different bases in shares of Series B Preferred Stock, then the amount allocated could reduce a portion of the basis in certain shares while reducing all of the basis, and giving rise to taxable gain, in other shares. Thus, such U.S. holder could have gain even if such U.S. holder’s aggregate adjusted tax basis in all shares of Series B Preferred Stock held exceeds the aggregate amount of such distribution.
The proposed Treasury regulations permit the transfer of basis in the redeemed shares of the Series B Preferred Stock to the U.S. holder’s remaining, unredeemed Series B Preferred stock (if any), but not to any other class of stock held, directly or indirectly, by the U.S. holder. Any unrecovered basis in the Series B Preferred Stock would be treated as a deferred loss to be recognized when certain conditions are satisfied. The proposed Treasury regulations would be effective for transactions that occur after the date the regulations are published as final Treasury regulations. There can, however, be no assurance as to whether, when and in what particular form such proposed Treasury regulations are ultimately finalized.
Information Reporting and Backup Withholding. Information reporting and backup withholding may apply with respect to payments of dividends on the Series B Preferred Stock and to certain payments of proceeds on the sale or other disposition of Series B Preferred Stock. Certain non-corporate U.S. holders may be subject to U.S. backup withholding (currently at a rate of 28%) on payments of dividends on the Series B Preferred Stock and certain payments of proceeds on the sale or other disposition of our Series B Preferred Stock unless the beneficial owner thereof furnishes the payor or its agent with a taxpayer identification number, certified under penalties of perjury, and certain other information, or otherwise establishes, in the manner prescribed by law, an exemption from backup withholding.
U.S. backup withholding tax is not an additional tax. Any amounts withheld under the backup withholding rules may be allowed as a refund or a credit against a U.S. holder’s U.S. federal income tax liability, which may entitle the U.S. holder to a refund, provided the U.S. holder timely furnishes the required information to the Internal Revenue Service.
Non-U.S. holders:
You are a “Non-U.S. holder” if you are a beneficial owner of Series B Preferred Stock and you are not a “U.S. holder.”
Distributions on the Series B Preferred Stock. If distributions (whether in cash or our common stock coveredor Series B Preferred Stock including constructive distributions as discussed under the heading “Material U.S. Federal Income Tax Consequences—U.S. holders: Distributions of Additional Shares of Common Stock or Series B Preferred Stock”) are made with respect to our Series B Preferred Stock, such distributions will be treated as dividends to the extent of our current and accumulated earnings and profits as determined under the Code and may be subject to withholding as discussed below. Any portion of a distribution that exceeds our current and accumulated earnings and profits will first be applied to reduce the Non-U.S. holder’s basis in the Series B Preferred Stock and, to the extent such portion exceeds the Non-U.S. holder’s basis, the excess will be treated as gain from the disposition of the Series B Preferred Stock, the tax treatment of which is discussed below under “Material U.S. Federal Income Tax Consequences—Non-U.S. holders: Disposition of Series B Preferred Stock, Including Redemptions.” In addition, if we are a U.S. real property holding corporation, i.e. a “USRPHC,” which we believe that we are currently, and any distribution exceeds our current and accumulated earnings and profits, we will need to choose to satisfy our withholding requirements either by treating the entire distribution as a dividend, subject to the withholding rules in the following paragraph (and withhold at a minimum rate of 10% or such lower rate as may be specified by an applicable income tax treaty for distributions from a USRPHC), or by treating only the amount of the distribution equal to our reasonable estimate of our current and accumulated earnings and profits as a dividend, subject to the withholding rules in the following paragraph, with the excess portion of the distribution subject to withholding at a rate of 10% or such lower rate as may be specified by an applicable income tax treaty as if such excess were the result of a sale of shares in a USRPHC (discussed below under “Material U.S. Federal Income Tax Consequences—Non-U.S. holders: Disposition of Series B Preferred Stock, Including Redemptions”), with a credit generally allowed against the Non-U.S. holder’s U.S. federal income tax liability in an amount equal to the amount withheld from such excess.
Dividends paid to a Non-U.S. holder of our Series B Preferred Stock will be subject to withholding of U.S. federal income tax at a 30% rate or such lower rate as may be specified by an applicable income tax treaty. However, dividends that are effectively connected with the conduct of a trade or business by the Non-U.S. holder within the United States (and, where a tax treaty applies, are attributable to a permanent establishment maintained by the Non-U.S. holder in the United States) are not subject to the withholding tax, provided certain certification and disclosure requirements are satisfied including completing Internal Revenue Service Form W-8ECI (or other applicable form). Instead, such dividends are subject to U.S. federal income tax on a net income basis in the same manner as if the Non-U.S. holder were a United States person as defined under the Code, unless an applicable income tax treaty provides otherwise. Any such effectively connected dividends received by a foreign corporation may be subject to an additional “branch profits tax” at a 30% rate or such lower rate as may be specified by an applicable income tax treaty.
A Non-U.S. holder of our Series B Preferred Stock who wishes to claim the benefit of an applicable treaty rate and avoid backup withholding, as discussed below, for dividends will be required to (a) complete Internal Revenue Service Form W-8BEN (or other applicable form) and certify under penalties of perjury that such Non-U.S. holder is not a United States person as defined under the Code and is eligible for treaty benefits, or (b) if our Series B Preferred Stock is held through certain foreign intermediaries, satisfy the relevant certification requirements of applicable Treasury regulations.
A Non-U.S. holder of our Series B Preferred Stock eligible for a reduced rate of U.S. withholding tax pursuant to an income tax treaty may obtain a refund of any excess amounts withheld by timely filing an appropriate claim for refund with the Internal Revenue Service.
Disposition of Series B Preferred Stock, Including Redemptions. Any gain realized by a Non-U.S. holder on the disposition of our Series B Preferred Stock will not be subject to U.S. federal income or withholding tax unless:
| · | the gain is effectively connected with a trade or business of the Non-U.S. holder in the United States (and, if required by an applicable income tax treaty, is attributable to a permanent establishment maintained by the Non-U.S. holder in the United States); |
| · | the Non-U.S. holder is an individual who is present in the United States for 183 days or more in the taxable year of disposition, and certain other conditions are met; or |
| · | we are or have been a USRPHC for U.S. federal income tax purposes, as such term is defined in Section 897(c) of the Code, and such Non-U.S. holder owned beneficially (directly or pursuant to attribution rules) more than 5% of the total fair market value of our Series B Preferred Stock at any time during the five year period ending either on the date of disposition of such interest or other applicable determination date. This assumes that our Series B Preferred Stock is regularly traded on an established securities market, within the meaning of Section 897(c)(3) of the Code. We believe we are currently a USRPHC and that our Series B Preferred Stock will be regularly traded on an established securities market though no assurances can be made this will be the case in the future. |
A Non-U.S. holder described in the first bullet point immediately above will generally be subject to tax on the net gain derived from the sale under regular graduated U.S. federal income tax rates in the same manner as if the Non-U.S. holder were a United States person as defined under the Code, and if the Non-U.S. holder is a corporation, may also be subject to the branch profits tax equal to 30% of its effectively connected earnings and profits or at such lower rate as may be specified by an applicable income tax treaty. An individual Non-U.S. holder described in the second bullet point immediately above will be subject to a flat 30% tax (or at such reduced rate as may be provided by an applicable treaty) on the gain derived from the sale, which may be offset by U.S. source capital losses, even though the individual is not considered a resident of the United States. A Non-U.S. holder described in the third bullet point above will be subject to U.S. federal income tax under regular graduated U.S. federal income tax rates with respect to the gain recognized in the same manner as if the Non-U.S. holder were a United States person as defined under the Code.
If a Non-U.S. holder is subject to U.S. federal income tax on any sale, exchange, redemption (except as discussed below), or other disposition of the Series B Preferred Stock, such Non-U.S. holder will recognize capital gain or loss equal to the difference between the amount realized by the Non-U.S. holder and the Non-U.S. holder’s adjusted tax basis in the Series B Preferred Stock. Such capital gain or loss will be long-term capital gain or loss if the Non-U.S. holder’s holding period for the Series B Preferred Stock is longer than one year. A Non-U.S. holder should consult its own tax advisors with respect to applicable tax rates and netting rules for capital gains and losses. Certain limitations exist on the deduction of capital losses by both corporate and non-corporate taxpayers.
If a Non-U.S. holder is subject to U.S. federal income tax on any disposition of the Series B Preferred Stock, a redemption of shares of the Series B Preferred Stock will be a taxable event. If the redemption is treated as a sale or exchange, instead of a dividend, a Non-U.S. holder generally will recognize long-term capital gain or loss, if the Non-U.S. holder’s holding period for such Series B Preferred Stock exceeds one year, equal to the difference between the amount of cash received and fair market value of property received and the Non-U.S. holder’s adjusted tax basis in the Series B Preferred Stock redeemed, except that to the extent that any cash received is attributable to any accrued but unpaid dividends on the Series B Preferred Stock, which generally will be subject to the rules discussed above in “Material U.S. Federal Income Tax Consequences—Non-U.S. holders: Distributions on the Series B Preferred Stock.” A payment made in redemption of Series B Preferred Stock may be treated as a dividend, rather than as payment in exchange for the Series B Preferred Stock, in the same circumstances discussed above under “Material U.S. Federal Income Tax Consequences—U.S. holders: Disposition of Series B Preferred Stock, Including Redemptions.” Each Non-U.S. holder of Series B Preferred Stock should consult its own tax advisors to determine whether a payment made in redemption of Series B Preferred Stock will be treated as a dividend or as payment in exchange for the Series B Preferred Stock.
Information Reporting and Backup Withholding. We must report annually to the Internal Revenue Service and to each Non-U.S. holder the amount of dividends paid to such Non-U.S. holder and the tax withheld with respect to such dividends, regardless of whether withholding was required. Copies of the information returns reporting such dividends and withholding may also be made available to the tax authorities in the country in which the Non-U.S. holder resides under the provisions of an applicable income tax treaty.
A Non-U.S. holder will not be subject to backup withholding on dividends paid to such Non-U.S. holder as long as such Non-U.S. holder certifies under penalties of perjury that it is a Non-U.S. holder (and the payor does not have actual knowledge or reason to know that such Non-U.S. holder is a United States person as defined under the Code), or such Non-U.S. holder otherwise establishes an exemption.
Depending on the circumstances, information reporting and backup withholding may apply to the proceeds received from a sale or other disposition of our Series B Preferred Stock unless the beneficial owner certifies under penalties of perjury that it is a Non-U.S. holder (and the payor does not have actual knowledge or reason to know that the beneficial owner is a United States person as defined under the Code), or such owner otherwise establishes an exemption.
U.S. backup withholding tax is not an additional tax. Any amounts withheld under the backup withholding rules may be allowed as a refund or a credit against a Non-U.S. holder’s U.S. federal income tax liability provided the required information is timely furnished to the Internal Revenue Service.
Recently Enacted Legislation Relating to Foreign Accounts. Recently enacted legislation (“FATCA”) will generally impose a 30% withholding tax on dividends on Series B Preferred Stock and the gross proceeds of a disposition of Series B Preferred Stock that are paid to: (i) a foreign financial institution (as that term is defined in Section 1471(d)(4) of the Code and the Treasury regulations thereunder) unless that foreign financial institution enters into an agreement with the U.S. Treasury Department to collect and disclose information regarding U.S. account holders of that foreign financial institution (including certain account holders that are foreign entities that have U.S. owners) and satisfies other requirements, or is otherwise exempt from FATCA withholding; and (ii) a “non-financial foreign entity” (as that term is defined in Section 1472(d) of the Code and the Treasury regulations thereunder) unless such entity certifies that it does not have any substantial U.S. owners or provides the name, address and taxpayer identification number of each substantial U.S. owner and such entity satisfies other specified requirements, or otherwise is exempt from FATCA withholding. A Non-U.S. holder should consult its own tax advisors regarding the application of this legislation to it. According to recently issued guidance from the Internal Revenue Service, FATCA withholding will apply to dividends paid on shares of our Series B Preferred Stock starting January 1, 2014, and to gross proceeds from the disposition of shares of our Series B Preferred Stock starting January 1, 2017.
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USE OF PROCEEDS
At our offering price of $ per share, the midpoint of the range on the front cover of this prospectus, for its own account. Accordingly, we will not receive anyestimate the net proceeds to us from the sale of shares of Series B Preferred Stock that we are selling in this offering will be approximately $[·], after deducting the underwriting commissions and estimated offering expenses payable by Paladin. Allus. A $1.00 increase or decrease in the assumed public offering price of $[·] per share would increase or decrease, respectively, the net proceeds of to us by approximately $ [·], assuming that the number of shares offered by us set forth on the cover page of this prospectus remains the same and after deducting the underwriting commissions and estimated offering expenses payable by us.
We intend to use the net proceeds from the sale of the securities offered by us under this prospectus primarily for capital expenditures to accelerate the development of our oil and natural gas properties located in Eastern Kansas and Easter Colorado. We also may use such proceeds for general corporate purposes including acquisitions, although we do not currently have any agreements, understandings or arrangements with respect to any potential acquisitions. We have historically drawn on our senior revolving credit facility with Texas Capital Bank, N.A. to fund our capital expenditures. We intend to temporarily reduce the amount outstanding under this facility with proceeds from this offering only to reduce interest expenses during the period in which such capital is deployed. We do not intend to use any proceeds from this offering to permanently repay debt.
The actual use of proceeds in the offering may vary from that set forth herein as our management has the discretion to apply the proceeds as they see fit, as management retains broad discretion as to the allocation of net proceeds from this offering.
MARKET PRICE OF AND DIVIDENDS ON ENERJEX COMMON STOCK
AND RELATED STOCKHOLDER MATTERS
EnerJex's common stock covered by this prospectus will go to Paladin. We will bear all expensesis quoted on the OTCQB under the symbol "ENRJ." The OTCQB is a regulated quotation service that displays real-time quotes, last-sale prices, and volume information in over-the-counter (OTC) equity securities. The OTCQB is a quotation medium for subscribing members, not an issuer listing service, and should not be confused with The NASDAQ Stock MarketSM or any other stock market. There is no established public trading market for our Series A preferred stock or Series B Preferred Stock. EnerJex's fiscal year ends on December 31st.
As of registration incurred in connection with this offering, including filing fees, printing fees, and expenses[Ÿ], 2014, there were [Ÿ] shares of our legal counselcommon stock issued and other experts, but all selling and other expenses incurred by the Selling Stockholder will be borne by the Selling Stockholder. However,outstanding. Additionally, we will receive proceeds from any sale ofhave 1,717,000 shares of common stock reserved for issuance upon exercise of outstanding stock options and up to Paladin pursuant to the SEDA.
Currently, there is only a limited public market for EnerJex stock on the SEDA, Paladin will payOTCQB. You should also note that the OTCQB is not a percentagelisting service or exchange, but is instead a dealer quotation service for subscribing members.At present, there is no liquid market for our Series B Preferred Shares. Consequently, unless such a market develops in the future, investors subscribing for shares of our Series B Preferred shares would need to be able to hold those shares indefinitely without having the lowest dailyopportunity to sell or otherwise dispose of such shares. In addition, even if a market develops for our Series B Preferred shares in the future, there can be no assurance regarding how active it may be, and if there is limited in the trading of such shares, then our Series B Preferred shares may be saleable only at a significant discount from the par value of those shares. If our Series B Preferred Stock is not quoted on the OTCQB or if a public market for our Series B Preferred Stock does not develop, then investors may not be able to resell the shares of its common stock that they have received and may lose all of their investment. If we do establish a trading market for our Series B Preferred Stock, the market price of our Series B Preferred Stock may be significantly affected by factors such as actual or anticipated fluctuations in its operating results, general market conditions and other factors. In addition, the stock market has from time to time experienced significant price and volume weighted averagefluctuations that have particularly affected the market prices for the shares of small companies, which may materially adversely affect the market price of our Series B Preferred Stock. Accordingly, investors may find that the price for our Series B Preferred Stock may be highly volatile and may bear no relationship to its actual financial condition or results of operations.
The following table sets forth the range of high and low closing bid quotations for our common stock during our most recent two years on the OTCQB. The quotations represent inter-dealer prices without retail markup, markdown or commission, and may not necessarily represent actual transactions.
EnerJex Common Stock
| High | Low | |||||||
| Year Ended December 31, 2011 | ||||||||
| Quarter ended September 30, 2011 | $ | 0.85 | $ | 0.20 | ||||
| Quarter ended December 31, 2011 | $ | 0.90 | $ | 0.22 | ||||
| Year Ended December 31, 2012 | ||||||||
| Quarter ended March 31, 2012 | $ | 0.90 | $ | 0.70 | ||||
| Quarter ended June 30, 2012 | $ | 0.78 | $ | 0.60 | ||||
| Quarter ended September 30, 2012 | $ | 0.74 | $ | 0.60 | ||||
| Quarter ended December 31, 2012 | $ | 0.73 | $ | 0.46 | ||||
| Year Ended December 31, 2013 | ||||||||
| Quarter ended March 31, 2013 | $ | 0.69 | $ | 0.46 | ||||
| Quarter ended June 30, 2013 | $ | 0.69 | $ | 0.48 | ||||
| Quarter ended September 30, 2013 | $ | 0.75 | $ | 0.46 | ||||
| Quarter ended December 31, 2013 | $ | 0.63 | $ | 0.41 | ||||
| Year Ended December 31, 2014 | ||||||||
| Quarter ending March 31, 2014 (through February 13, 2014) | $ | 0.58 | $ | 0.47 |
On February 13, 2014, the closing price during the five consecutive trading days after we provide notice to Paladin basedas reported on the following:
Dividend Policy
We have never paiddeclared or declared any cash dividends on our common stock. We currently intend to retain any future earnings to finance the growth and development of our business and we do not expect to pay anypaid cash dividends on our common stock and do not intend to pay any cash dividends in the foreseeable future. In addition, we are contractually prohibited by the termsHolders of our outstanding debt from payingSeries A preferred stock are eligible to receive dividends, and we regularly have paid such dividends to holders of our Series A Preferred Stock. Any future determination to pay cash dividends on ourthe common stock. Payment of future dividends, if any,stock will be at the discretion of our board of directors and will depend onupon our financial condition, operating results, of operations, capital requirements, restrictions containeddeployment of resources and ability to engage in currentstrategic transactions, whether or future financing instruments, includingnot the consent of debt holders, if applicable atmerger is consummated, and such time, and other factors as our board of directors deems relevant.
Holders of our Series B Preferred Stock will be entitled to receive, when and Analysisas declared by the board of Financial Conditiondirectors, out of funds legally available for the payment of dividends, cumulative cash dividends on the Series B Preferred Stock at a rate of [·]% per annum of the $25.00 liquidation preference per share (equivalent to $[·] per annum per share). However, under certain conditions relating to our non-payment of dividends on the Series B Preferred Stock, the dividend rate on the Series B Preferred Stock may increase to [·]% per annum, which we refer to as the “Penalty Rate.” Dividends will generally be payable on the 31st day of January, July and ResultsOctober and the 30th day of OperationsJanuary, commencing [·” and our financial statements and related notes included elsewhere in this prospectus.
| • | our senior shares or our agreements, including our credit facilities, at any time prohibit the current payment of dividends; | |||
| • | we have earnings; | |||
| • | there are funds legally available for the payment of such dividends; or | |||
| • | ||||
All payments of dividends made to the holders of Series B Preferred Stock will be credited against the previously accrued dividends on such shares of Series B Preferred Stock. We will credit any dividends paid on the Series B Preferred Stock first to the earliest accrued and unpaid dividend due. The informationpayment of dividends with respect to the Series B Preferred Stock is subordinate to any dividends to which holders of our Series A Preferred Stock are entitled, if any, and subordinate upon liquidation to the holders of the Series A Preferred Stock receiving their full liquidation preference.
Under the terms of our Articles of Incorporation and applicable provisions of the Nevada Revised Statutes, we are not able to make any distributions if we are then insolvent or to the extent that the distribution would cause us to be insolvent. We do not believe that we are presently insolvent. If, in the table above excludes:
| Low | High | |||||||
| Fiscal 2008 | ||||||||
| Quarter ended June 30, 2007 | $ | 5.00 | $ | 6.25 | ||||
| Quarter ended September 30, 2007 | $ | 3.75 | $ | 6.75 | ||||
| Quarter ended December 31, 2007 | $ | 3.50 | $ | 6.00 | ||||
| Quarter ended March 31, 2008 | $ | 4.05 | $ | 6.00 | ||||
| Fiscal 2009 | ||||||||
| Quarter ended June 30, 2008 | $ | 4.80 | $ | 5.90 | ||||
| Quarter ended September 30, 2008 | $ | 4.00 | $ | 5.10 | ||||
| Quarter ended December 31, 2008 | $ | 0.45 | $ | 3.16 | ||||
| Quarter ended March 31, 2009 | $ | 0.25 | $ | 1.88 | ||||
| Fiscal 2010 | ||||||||
| Quarter ended June 30, 2009 | $ | 0.15 | $ | 1.34 | ||||
| Quarter ending September 30, 2009 | $ | 0.15 | $ | 1.85 | ||||
| Quarter ending December 31, 2009 (through December 3, 2009) | $ | 0.45 | $ | 1.00 | ||||
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
You should read the following discussion and analysis of our financial condition and results of operations should be read in conjunctiontogether with ourthe "Selected Historical Financial Data of EnerJex" section of this prospectus and EnerJex's financial statements and the related notes to our financial statements included elsewhere in this prospectus. In addition to historical financial information, the following discussion and analysis contains forward-looking statements that involve risks, uncertainties and assumptions. OurEnerJex's actual results and timing of selected events maycould differ materially from those anticipated in theseby the forward-looking statements as a result of manydue to important factors including, but not limited to, those discussed under “Risk Factors” and elsewhereset forth in the "Risk Factors—Risks Related to EnerJex" section of this prospectus.
Business Overview
Our principal strategy is to focus on the acquisition ofacquire and develop oil and natural gas mineral leases that have existing production and cash flow. Once acquired, subject to availability of capital, we strive to implement an accelerated development program utilizing capital resources, a regional operating focus, an experienced management and technical team, and enhanced recovery technologies to attempt to increase production and increase returns for our stockholders. Our oil and natural gas acquisition and development activities are currently focused in Eastern Kansas.
Recent Developments
On July 23, 2013, EnerJex, BRE Merger Sub, Inc., a Delaware corporation and a wholly owned subsidiary of EnerJex (Merger Sub), and Black Raven Energy, Inc., a Nevada corporation, entered into an agreement and plan of merger (Merger Agreement) pursuant to further develop current leases, restructuring current debt, as well as evaluating other options ranging from capital formation via additional debt or equity raising, to some typewhich Black Raven would be merged with and into Merger Sub and after which Black Raven would be a wholly owned subsidiary of business combination. We are continually evaluating oil and natural gas opportunities in Eastern Kansas and anticipate that this economic strategy would allow us to utilize our own financial assets towardEnerJex.
On September 27, 2013, the growthtransactions contemplated by the Merger Agreement were successfully completed.
The following transactions were executed on September 27, 2013 per the terms of our leased acreage holdings, pursue the acquisition of strategic oil and natural gas producing properties or companies and generally expand our existing operations while further diversifying risk. Subject to availabilityMerger Agreement: (i) shares of capital westock of Black Raven were converted into (a) cash totaling $207,067 and (b) 41,328,914 shares of EnerJex common stock, (ii) all options under the Black Raven option plan to continue to bring potential acquisitionwere cancelled, and JV opportunities to various financial partners for evaluation and funding options. It is our vision to grow the business in a disciplined and well-planned manner. However, there can be no assurance that we will be successful in any of these respects, that the prices of oil and natural gas prevailing at the time of production will be at a level allowing for profitable production,(iii) all warrants or that we will be able to obtain additional funding at terms favorable to us to increase our currently limited capital resources.
At closing of the transactions contemplated by the Merger Agreement, the previous stockholders of Black Raven owned approximately 38% of the outstanding voting stock of EnerJex and its subsidiaries. The Credit Facility has a termthe previous stockholders of three years,EnerJex owned approximately 62% of the outstanding voting stock of EnerJex.
Critical Accounting Policies and all unpaid principal and interest will be due and payableEstimates
EnerJex's significant accounting policies are described in full on July 3, 2011. The Credit Facility also providesNote 2 to EnerJex's financial statements for the issuanceyear ended December 31, 2012 included in this document. The discussion and analysis of letters-of-credit upEnerJex's financial statements and results of operations are based upon EnerJex's financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. The discussion and analysis of EnerJex's financial statements and results of operations are based upon EnerJex's financial statements, which have been prepared in accordance with GAAP. The preparation of EnerJex's financial statements requires management to make estimates and judgments that affect the reported amount of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. The SEC has defined a $750,000 sub-limit under the borrowing base and up to an additional $2.25 million limit not subjectcompany's most critical accounting policies as those that are most important to the borrowing baseportrayal of its financial condition and results of operations, and which requires EnerJex to support our hedging program. We had borrowings $7.328make its most difficult and subjective judgments, often as a result of the need to make estimates of matters that are inherently uncertain. Based on this definition, EnerJex has identified the critical accounting policy described below. Although EnerJex believes that its estimates and assumptions are reasonable, they are based upon information available when they are made. Actual results may differ significantly from these estimates under different assumptions or conditions.
Results of Operations
The following table sets forth, for the periods indicated, EnerJex's results of operations.
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | Difference | ||||||||||
| Oil revenues (1) | $ | 8,469,519 | $ | 6,285,411 | $ | 2,184,108 | ||||||
| Average price per barrel | $ | 87.74 | $ | 87.63 | $ | 0.11 | ||||||
| Expenses: | ||||||||||||
| Direct operating costs (2) | $ | 3,102,321 | $ | 3,671,228 | $ | (568,907 | ) | |||||
| Depreciation, depletion and amortization (3) | 1,541,069 | 1,128,712 | 412,357 | |||||||||
| Total production expenses | 4,643,390 | 4,799,940 | (156,550 | ) | ||||||||
| Professional fees (4) | 1,483,720 | 1,453,386 | 30,334 | |||||||||
| Salaries (5) | 601,533 | 502,924 | 98,609 | |||||||||
| Depreciation on other fixed assets | 92,398 | 15,731 | 76,667 | |||||||||
| Administrative expenses (6) | 808,836 | 945,013 | (136,177 | ) | ||||||||
| Total expenses | $ | 7,629,877 | $ | 7,716,994 | $ | (87,117 | ) | |||||
(1) 2012 revenues increased 35% to $8.5 million outstanding at March 31, 2009. Subsequentfrom $6.3 million during fiscal year 2011. Revenues increased due to year-end, we have made Borrowing Base Reduction payments of $200,000.
Fiscal Year Ended March 31, | ||||||||||||
| 2009 | 2008 | Increase / (Decrease) | ||||||||||
| Amount | Amount | $ | ||||||||||
| Oil and natural gas revenues | $ | 6,436,805 | $ | 3,602,798 | $ | 2,834,007 | ||||||
(2) 2012 lease operating expenses decreased 10% to $3.1 million from $3.7 million during 2011. Lease operating expenses decreased due to several factors, including the sale of non-core properties in December 2011, and due to increased leveraging of fixed costs associated with the Cherokee project operations. Lease operating expenses per barrel of oil. The average pricedecreased 33% to $32.03 in 2012 from $47.96 per barrel we received for oil sold during the twelve months ended March 31, 2009 was $85.67in 2011. Lease operating expenses include transportation expenses, which are paid to our purchasers as part of our price differential.
(3) 2012 depletion expense increased 45% to $1.6 million compared to $79.71 for the twelve months ended March 31, 2008. Natural gas sales accounted for less than 1% of the total revenues. The average price per Mcf for natural gas sales during the fiscal year ended March 31, 2009 was $5.57, compared to $6.20 during the fiscal year ended March 31, 2008.
Fiscal Year Ended March 31, | ||||||||||||
| 2009 | 2008 | Increase / (Decrease) | ||||||||||
| Amount | Amount | $ | ||||||||||
| Expenses: | ||||||||||||
| Direct operating costs | $ | 2,637,333 | $ | 1,795,188 | $ | 842,145 | ||||||
| Depreciation, depletion and amortization | 872,230 | 913,224 | (40,994 | ) | ||||||||
| Total production expenses | 3,509,563 | 2,708,412 | 801,151 | |||||||||
| Professional fees | 1,320,332 | 1,226,998 | 93,334 | |||||||||
| Salaries | 849,340 | 1,703,099 | (853,759 | ) | ||||||||
| Depreciation on other fixed assets | 39,063 | 22,106 | 16,957 | |||||||||
| Administrative expenses | 1,392,645 | 887,872 | 504,773 | |||||||||
| Impairment of oil & gas properties | 4,777,723 | - | 4,777,723 | |||||||||
| Total expenses | $ | 11,888,666 | $ | 6,548,487 | $ | 5,340,179 | ||||||
(4) 2012 professional fees were $1.5 million, unchanged from $1.5 million during 2011. Professional fees decreased as a result of reduced legal fees and investment banking fees associated with the lower cost per barrel of depletion of oil reserves.capital raising transactions in 2011. The rate of depletiondecrease was $12.02 per barrel for the fiscal year ended March 31, 2009 asoffset by increases in consulting fees, engineering fees, legal fees, and audit fees incurred in 2012.
(5) 2012 salaries and wages expenses increased 20% to $0.6 million compared to $19.57 per barrel for the fiscal year ended March 31, 2008.
(6) 2012 administrative expenses decreased 14% to growth in operations.
| Proved Reserves Category | Gross | Net | PV10 (before tax)(1) | |||||||||
| Proved, Developed Producing | ||||||||||||
| Oil (stock-tank barrels) | 722,590 | 429,420 | $ | 6,691,550 | ||||||||
Natural Gas (mcf)(2) | - | - | - | |||||||||
| Proved, Developed Non-Producing | ||||||||||||
| Oil (stock-tank barrels) | 146,620 | 95,560 | $ | 1,459,280 | ||||||||
Natural Gas (mcf) (2) | - | - | - | |||||||||
| Proved, Undeveloped | ||||||||||||
| Oil (stock-tank barrels) | 1,440,760 | 811,650 | $ | 2,478,510 | ||||||||
Natural Gas (mcf) (2) | - | - | - | |||||||||
| Total Proved Reserves | ||||||||||||
| Oil (stock-tank barrels) | 2,309,970 | 1,136,630 | $ | 10,629,340 | ||||||||
Natural Gas (mcf) (2) | - | - | - | |||||||||
As of March 31, 2009 | ||||
| PV10 (before tax) | $ | 10,629,340 | ||
| Future income taxes, net of 10% discount | - | |||
| Standardized measure of discounted future net cash flows | $ | 10,629,340 | ||
| Three Months Ended | Increase / | Six Months Ended | Increase / | |||||||||||||||||||||
| September 30, | (Decrease) | September 30, | (Decrease) | |||||||||||||||||||||
| 2009 | 2008 | $ | 2009 | 2008 | $ | |||||||||||||||||||
| Oil and natural gas revenues | $ | 1,394,117 | $ | 1,777,656 | $ | (383,539 | ) | $ | 2,789,179 | $ | 3,467,742 | $ | (678,563 | ) | ||||||||||
| Three Months Ended | Increase / | Six Months Ended | Increase / | |||||||||||||||||||||
| September 30, | (Decrease) | September 30, | (Decrease) | |||||||||||||||||||||
| 2009 | 2008 | $ | 2009 | 2008 | $ | |||||||||||||||||||
| Production expenses: | ||||||||||||||||||||||||
| Direct operating costs | $ | 430,316 | $ | 816,767 | $ | (386,451 | ) | $ | 864,835 | $ | 1,531,300 | $ | (666,465 | ) | ||||||||||
| Depreciation, depletion and amortization | 289,604 | 347,859 | (58,255 | ) | 445,895 | 718,048 | (272,153 | ) | ||||||||||||||||
| Total production expenses | 719,920 | 1,164,626 | (444,706 | ) | 1,310,730 | 2,249,348 | (938,618 | ) | ||||||||||||||||
| General expenses: | ||||||||||||||||||||||||
| Professional fees | 310,455 | 171,083 | 139,372 | 419,139 | 294,785 | 124,354 | ||||||||||||||||||
| Salaries | 399,254 | 276,939 | 122,315 | 552,989 | 494,426 | 58,563 | ||||||||||||||||||
| Administrative expense | 264,714 | 557,664 | (292,950 | ) | 455,316 | 836,430 | (381,113 | ) | ||||||||||||||||
| Total general expenses | 974,423 | 1,005,686 | (31,263 | ) | 1,427,444 | 1,625,641 | (198,195 | ) | ||||||||||||||||
| Total production and general expenses | 1,694,343 | 2,170,312 | (475,969 | ) | 2,738,174 | 3,874,989 | (1,136,815 | ) | ||||||||||||||||
| Other income (expense) | ||||||||||||||||||||||||
| Interest expense | (174,727 | ) | (258,237 | ) | (83,510 | ) | (353,565 | ) | (532,624 | ) | (179,059 | ) | ||||||||||||
| Loan interest accretion | (144,101 | ) | (2,224,554 | ) | (2,080,453 | ) | (279,490 | ) | (2,567,379 | ) | (2,287,889 | ) | ||||||||||||
| Gain on repurchase of debentures | - | - | 406,500 | - | (406,500 | ) | ||||||||||||||||||
| Management fee revenue | 75,291 | - | (75,291 | ) | 75,291 | - | (75,291 | ) | ||||||||||||||||
| Total other income (expense) | (243,537 | ) | (2,482,791 | ) | (2,239,028 | ) | (151,264 | ) | (3,100,003 | ) | (2,948,739 | ) | ||||||||||||
| Net income (loss) | $ | (543,763 | ) | $ | (2,875,447 | ) | $ | (2,331,684 | ) | $ | (100,259 | ) | (3,507,250 | ) | $ | (3,406,991 | ) | |||||||
Liquidity and Capital Resources
Liquidity is a measure of a company’scompany's ability to meet potential cash requirements. We have historically met our capital requirements through debt financing, revenues from operations and the issuance of equity securities. Based uponWe believe that our historical means of meeting our capital requirements will provide us with adequate liquidity to fund our operations and capital program in 2013.
The following table summarizes total assets, total liabilities and working capital at year ended December 31, 2012, as compared to the monthly commitment notices we have receivedyear ended December 31, 2011.
The working capital deficit as of December 31, 2012, includes approximately $492k of accounts payable to date, we have estimatedHush Blackwell LLP, which are currently in dispute. The working capital deficit also includes an $825,000 promissory note related to the common stock and classified $300,000 of the borrowings outstanding under our Credit Facility asasset repurchase from Enutroff, LLC. The promissory note will fully amortize during 2013 and is therefore considered a current liability. As we may be unable to provide the necessary liquidity we need by the revenues generated from our net interests in our oil and natural gas production at current commodity prices, we are exploring various strategic initiatives and JV partnerships, as well as sales of reserves in our existing properties to finance our operations and to service our debt obligations.
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | Difference | ||||||||||
| Current Assets | $ | 3,382,621 | $ | 5,357,854 | $ | (1,975,233 | ) | |||||
| Current Liabilities | $ | 4,381,712 | $ | 3,445,596 | $ | (936,116 | ) | |||||
| Working Capital (deficit) | $ | (999,091 | ) | $ | 1,912,258 | $ | (2,911,349 | ) | ||||
The following table summarizes total current assets, total current liabilities and working capital at Septemberas of June 30, 20092013 and as compared to MarchDecember 31, 2009.
September 30, 2009 | March 31, 2009 | Increase / (Decrease) $ | ||||||||||
| Current Assets | $ | 825,923 | $ | 898,941 | (73,018 | ) | ||||||
| Current Liabilities | $ | 1,158,586 | $ | 2,827,015 | (1,668,429 | ) | ||||||
| Working Capital (deficit) | $ | (332,663 | ) | $ | (1,928,074 | ) | (1,595,411 | ) | ||||
2012.
| June 30, 2013 | December 31, 2012 | Increase / (Decrease) | ||||||||||
| Current Assets | $ | 2,849,602 | $ | 3,536,497 | $ | (686,895 | ) | |||||
| Current Liabilities | $ | 3,296,417 | $ | 4,556,476 | $ | (1,260,059 | ) | |||||
| Working Capital (deficit) | $ | (446,815 | ) | $ | (1,019,979 | ) | $ | (573,164 | ) | |||
Senior Secured Credit Facility
On JulyOctober 3, 2008,2011, EnerJex EnerJex Kansas, and DD Energy, Inc., EnerJex Kansas, Inc., Black Sable Energy, LLC and Working Interest, LLC (Borrowers) entered into a three-year $50 million Senior Securedan Amended and Restated Credit Facility (the “Credit Facility”)Agreement with Texas Capital Bank, N.A. Borrowingsand other financial institutions and banks that may become a party to the Credit Agreement from time to time. The facilities provided under the Amended and Restated Credit FacilityAgreement are to be used to refinance Borrowers prior outstanding revolving loan facility with Bank, dated July 3, 2008, and for working capital and general corporate purposes.
At Borrowers option, loans under the facility will bear stated interest based on the Base Rate plus Base Rate Margin, or Floating Rate plus Floating Rate Margin (as those terms are defined in the Credit Agreement). The Base Rate will be, subjectfor any day, a fluctuating rate per annum equal to the higher of (a) the Federal Funds Rate plus 0.50% and (b) the Bank's prime rate. The Floating Rate shall mean, at Borrower's option, a borrowing base limitationper annum interest rate equal to (i) the Eurodollar Rate plus Eurodollar Margin, or (ii) the Base Rate plus Base Rate Margin (as those terms are defined in the Amended and Restated Credit Agreement). Eurodollar borrowings may be for one, two, three, or six months, as selected by the Borrowers. The margins for all loans are based on our current proved oila pricing grid ranging from 0.00% to 0.75% for the Base Rate Margin and gas reserves2.25% to 3.00% for the Floating Rate Margin based on the Company's Borrowing Base Utilization Percentage (as defined in the Amended and will be subjectRestated Credit Agreement).
Borrowers entered into a First Amendment to semi-annual redeterminations.Amended and Restated Credit Agreement and Second Amended and Restated Promissory Note in the amount of $50,000,000 with the Texas Capital Bank, which closed on December 15, 2011. The Amendment reflected the addition of Rantoul Partners, as an additional Borrower and added as additional security for the loans the assets that were held by Rantoul Partners.
In August 31, 2012, Borrowers entered into a Second Amendment to the Amended and Restated Credit Facility is secured by a lien on substantially all assetsAgreement with Texas Capital Bank. The Second Amendment reflects the following changes: (i) the reduction of the Company and its subsidiaries. The Credit Facility has a term of three years, and all principal amounts, together with all accrued and unpaidminimum interest will be due and payablerate to 3.75%, ii) an increase in full on July 3, 2011. The Credit Facility also provides for the issuance of letters-of-credit up to a $750,000 sub-limit under the borrowing base and up to an additional $2.25 million limit not subject to the borrowing base to support our hedging program.
On November 2, 2012, Borrowers entered into a Third Amendment to the Amended and Restated Credit Agreement with Texas Capital Bank’s acquisitionBank. The Third Amendment reflects the following changes: i) an increase in the borrowing base to $12.150 million, ii) the addition of our approximately $2.0 million indebtednessa provision permitting the repurchase of up to Cornerstone$2,000,000 of common stock on or before December 31, 2013, subject to certain liquidity requirements, iii) the amendment of certain financial covenant definitions for the purposes of clarity, and iv) the provision of a limited waiver for the failure to comply with the Interest Coverage Ratio for the period ending December 31, 2011.
On January 24, 2013, Borrowers entered into a Fourth Amendment to Amended and Restated Credit Agreement, which was made effective as of December 31, 2012 with Texas Capital Bank. The Fourth Amendment reflects the following changes: i) Texas Capital Bank (3) for complete repayment of promissory notes issuedconsented to the sellers in connection with our purchase of the DD Energy project in an aggregate principal amount of $965,000 plus accrued interest, (4) to pay transaction costs, fees and expensesrestructuring transactions related to the Credit Facility,dissolution of Rantoul Partners, and (5) to expand our current development projects. Future borrowings may be used for the acquisition, development and exploration of oil and gas properties, capital expenditures and general corporate purposes.
On April 16, 2013, Texas Capital Bank increased Borrowers current borrowing base to $19.5 million, of which we had borrowed $11.0 million as of June 30, 2013. We intend to conduct an additional borrowing base review in the formthird quarter of either2013 and we expect increases in our oil production and the maturity of our existing oil producing wells to result in an additional borrowing base rate loans or Eurodollar loans.increase.
On September 30, 2013, Borrowers entered into a Fifth Amendment to Amended and Restated Credit Agreement (the Fifth Amendment) with Texas Capital Bank. The interest rate onFifth Amendment: (i) expanded the base rate loans fluctuates based upon the higher of (1) the lender’s “prime rate” and (2) the Federal Funds rate plus 0.50%, plus, in either case, a margin of between 0.0% and 0.5% depending on the percent ofprincipal commitment amount to $100,000,000; (ii) increased the borrowing base utilized at the time of the credit extension, but in no event shall be less than five percent (5.0%), The interest rate on the Eurodollar loans fluctuates based upon the applicable Libor rate, plus a margin of 2.25% to 2.75% depending on the percent of the borrowing base utilized at the time of the credit extensionon, but in no event shall be less than five percent (5.0%). We may select Eurodollar loans of one, two, three$38,000,000; (iii) added Black Raven Energy, Inc. and six months. A commitment fee of 0.375% on the unused portion of the borrowing base will accrue, and be payable quarterly in arrears.
Satisfaction of our cash obligations for the next 12 months
We intend to meet our monthly operating expensesnear term cash obligations through financings under our credit facility with Texas Capital Bank and service our debt obligations. We are actively seeking opportunities to raise funds through a debt or equity offering. In the event we cannot obtain additional capital through other means to allow us to pursue our strategic plan, this would materially impact not only our ability to continue our desired growth and execute our business strategy, but also to continue as a going concern. There is no assurance we would be able to obtain such financing on commercially reasonable terms, if at all. Failure to do so can have a material adverse effect on our business prospects, financial condition and results ofcash flow generated from operations.
Summary of product research and development
We do not anticipate performing any significant product research and development under our plan of operation until such time as we can raise adequate working capital to sustain our operations.
Expected purchase or sale of any significant equipment
We anticipate that we will purchase the necessary production and field service equipment required to produce oil and natural gas during our normal course of operations over the next twelve months.
Significant changes in the number of employees
There have been no significant changes in number of full time employees at our fiscal year ended March 31, 2009. Since November 2008, we have reduced personnel levels by 5 full time employees and 2 independent contractors in response to declining economic conditionswe currently have 18 full-time employees, including field personnel. As production and in an effort to reduce our operating and general expenses and cash outlay. As drilling and production activities increase or decrease, we may have to continue to adjust our technical, operational and administrative personnel as appropriate. We are using and will continue to use the services of independent consultants and contractors to perform various professional services, particularly in the area of land services, reservoir engineering, geology drilling, water hauling, pipeline construction, well design, well-site monitoring and surveillance, permitting and environmental assessment when it is prudent and necessary to do so.assessment. We believe that this use of third-party service providers may enhance our ability to contain operating and general expenses, and capital costs.
Off-Balance Sheet Arrangements
We do not have any off-balance sheet arrangements that have or are reasonably likely to have a current or future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that is material to investors.
Oil and Gas Properties:
The accounting for our business is subject to special accounting rules that are unique to the gas and oil industry. There are two allowable methods of accounting for oil and gas business activities: the successful efforts method and the full-cost method. We follow the full-cost method of accounting under which all costs associated with property acquisition, exploration and development activities are capitalized. We also capitalize internal costs that can be directly identified with our acquisition, exploration and development activities and do not include any costs related to production, general corporate overhead or similar activities.
Under the full-cost method, capitalized costs are amortized on a composite unit-of-production method based on proved gas and oil reserves. Depreciation, depletion and amortization expense is also based on the amount of estimated reserves. If we maintain the same level of production year over year, the depreciation, depletion and amortization expense may be significantly different if our estimate of remaining reserves changes significantly. Proceeds from the sale of properties are accounted for as reductions of capitalized costs unless such sales involve a significant change in the relationship between costs and the value of proved reserves or the underlying value of unproved properties, in which case a gain or loss is recognized. The costs of unproved properties are excluded from amortization until the properties are evaluated. We review all of our unevaluated properties quarterly to determine whether or not and to what extent proved reserves have been assigned to the properties, and otherwise if impairment has occurred. Unevaluated properties are assessed individually when individual costs are significant.
We review the carrying value of our gas and oil properties consideringunder the full-cost accounting methodology. Capitalizedrules of the SEC on a quarterly basis. This quarterly review is referred to as a ceiling test. Under the ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes, may not exceed an amount equal to the sum of the present value of estimated future net revenues (adjusted for cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. This sum which may not be exceeded is referred to as the “ceiling”. In calculating future net revenues, current SEC regulations require us to utilize prices atand costs used are those as of the end of the appropriate quarterly period. Such prices are utilized except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts, including the effects of derivatives qualifying as cash flow hedges. Two primary factors impacting this test are reserve levels and current prices, and their associated impact on the present value of estimated future net revenues. Revisions to estimates of gas and oil reserves and/or an increase or decrease in prices can have a material impact on the present value of estimated future net revenues. Any excess of the net book value, less deferred income taxes, is generally written off as an expense. Under SEC regulations, the excess above the ceiling is not expensed (or is reduced) if, subsequent to the end of the period, but prior to the release of the financial statements, gas and oil prices increase sufficiently such that an excess above the ceiling would have been eliminated (or reduced) if the increased prices were used in the calculations.
The process of estimating gas and oil reserves is very complex, requiring significant decisions in the evaluation of available geological, geophysical, engineering and economic data. The data for a given property may also change substantially over time as a result of numerous factors, including additional development activity, evolving production history and a continual reassessment of the viability of production under changing economic conditions. As a result, material revisions to existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the subjective decisions and variances in available data for various properties increase the likelihood of significant changes in these estimates.
As of December 31, 2012, approximately 100% of our proved reserves were evaluated by an independent petroleum consultant. All reserve estimates are prepared based upon a review of production histories and other geologic, economic, ownership and engineering data.
Asset Retirement Obligations:
The asset retirement obligation relates to the plug and abandonment costs when our wells are no longer useful. We determine the value of the liability by obtaining quotes for this service and estimate the increase we will face in the future. We then discount the future value based on an intrinsic interest rate that is appropriate for us. If costs rise more than what we have expected there could be additional charges in the future however we monitor the costs of the abandoned wells and we will adjust this liability if necessary.
Share-Based Payments:
The value we assign to the options and warrants that we issue is based on the fair market value as calculated by the Black-Scholes pricing model. To perform a calculation of the value of our options and warrants, we determine an estimate of the volatility of our stock. We need to estimate volatility because there has not been enough trading of our stock to determine an appropriate measure of volatility. We believe our estimate of volatility is reasonable, and we review the assumptions used to determine this whenever we issue a new equity instruments. If we have a material error in our estimate of the volatility of our stock, our expenses could be understated or overstated.
Effects of Inflation and Pricing
The oil and natural gas industry is very cyclical and the demand for goods and services of oil field companies, suppliers and others associated with the industry puts extreme pressure on the economic stability and pricing structure within the industry. Material changes in prices impact revenue stream, estimates of future reserves, borrowing base calculations of bank loans and value of properties in purchase and sale transactions. Material changes in prices can impact the value of oil and natural gas companies and their ability to raise capital, borrow money and retain personnel. We anticipate business costs and the demand for services related to production and exploration will fluctuate while the commodity prices for oil and natural gas, both remainremains volatile.
Recently Issued Accounting Pronouncements
EnerJex does not expect the adoption of any recent accounting pronouncements to have a material effect on its financial position, results of operations or cash flows.
| 28 |
BUSINESS AND PROPERTIES
Overview
We were formerly known as Millennium Plastics Corporation is an oil and natural gas acquisition, exploration and development company. Midwest Energy, Inc. waswere incorporated in the State of Nevada on December 30, 2005. In August of 2006, Millennium Plastics Corporation, followingMarch 31, 1999. We abandoned a reverse merger by and among us, Millennium Acquisition Sub (our wholly-owned subsidiary) and Midwest Energy, changed the focus of itsprior business plan fromfocusing on the development of biodegradable plastic materialsmaterials. In August 2006, we acquired Midwest Energy, Inc., a Nevada corporation, pursuant to a reverse merger. After the merger, Midwest Energy became a wholly owned subsidiary, and entered intoas a result of the oil and natural gas industry. In conjunctionmerger the former Midwest Energy stockholders controlled approximately 98% of our outstanding shares of common stock. We changed our name to EnerJex Resources, Inc. in connection with the change,merger, and in November 2007 we changed the company was renamedname of Midwest Energy (now our wholly owned subsidiary) to EnerJex Resources,Kansas, Inc.
Our principal strategy is to focus on the acquisition ofacquire and develop oil and natural gas mineral leases that have existing production and cash flow. Once acquired, subject to availabilityproperties located in the mid-continent region of capital, we strive to implement an accelerated development program utilizing capital resources, a regional operating focus, an experienced management and technical team, and enhanced recovery technologies to attempt to increase production and increase returns for our stockholders. Our oil and natural gas acquisition and development activities are currently focused in Eastern Kansas.
Our total net proved oil reserves increased from zero at Marchas of December 31, 2007 to 1.32012, were 2.9 million barrels of oil equivalent, or BOE, as of March 31, 2009.oil. Of the 1.32.9 million BOEbarrels of total proved reserves, approximately 39%53% are proved developed and approximately 61% are proved undeveloped. The proved developed reserves consist of 82%classified as proved developed producing reserves and 18%approximately 47% are classified as proved developed non-producing reserves.
The total proved PV10 (present value) of our proved reserves (“PV10”) as of MarchDecember 31, 20092012, was $10.63 million, based on an estimated oil price of $42.65 per barrel. PV10approximately $61 million. "PV10" means the estimated future gross revenue to be generated from the production of proved reserves, net of estimated production and future development and abandonment costs, using prices and costs in effect at the determination date, before income taxes, and without giving effect to non-property related expenses, discounted to a present value using an annual discount rate of 10% in accordance with the guidelines of the SEC. PV10 is a non-GAAP financial measure and generally differs from the standardized measure of discounted future net cash flows, the most directly comparable GAAP financial measure, because it does not include the effects of income taxes on future net revenues. See “Management’s Discussion
Recent Developments
On July 23, 2013, EnerJex, BRE Merger Sub, Inc., a Delaware corporation and Analysisa wholly owned subsidiary of Financial ConditionEnerJex (Merger Sub), and ResultsBlack Raven Energy, Inc., a Nevada corporation (Black Raven), entered into an agreement and plan of Operations-Reserves
On September 27, 2013, the comparable GAAP financial measure.
The following transactions were executed on September 27, 2013 per the terms of the United States. Initiatives include creating joint venturesMerger Agreement: (i) shares of capital stock of Black Raven were converted into (a) cash totaling $207,067 and (b) 41,328,914 shares of EnerJex common stock, (ii) all options under the Black Raven option plan were cancelled, and (iii) all warrants or other rights to further develop current leases, restructuring current debt,purchase shares of capital stock of Black Raven were converted into warrants to purchase EnerJex common stock. No fractional shares of EnerJex common stock were issued in connection with the Merger, and holders of Black Raven common stock were entitled to receive cash in lieu thereof. The board of directors and executive officers of EnerJex remained unchanged as well as evaluating other options ranging from capital formation to some typea result of business combination. Though there can be no assurance that any particular outcome will result from this process, we believe there are significant opportunities to increase our growth rates given current market conditions. We believe this process may create options that will allow us to better positionthe closing of the Merger.
At closing of the transactions contemplated by the Merger Agreement, the previous stockholders of Black Raven owned approximately 38% of the outstanding voting stock of EnerJex to take advantageand the previous stockholders of these opportunities.
Our Opportunity in Kansas
According to the Kansas Geological Survey, the State of Kansas has historically been one of the top 10 domestic oil producing regions in the United States. For the years ended December 31, 2008 and 2007, 39.6 million barrels and 36.6Approximately 44 million barrels of oil were produced in Kansas. Of the total barrels produced in Kansas in the calendar year ended December 2007, 15during 2012. Twenty companies accounted for approximately 29%35% of the state’s total production, with the remaining 71%65% produced by over 1,750more than 3,500 active producers.
In addition to significant historical oil and natural gas production levels in the region, we believe that a confluence of the following factors in Eastern Kansas and the surrounding region make it an attractive area for oil and natural gas development activities:
| · |
| · | ||
| · | Opportunity to Reduce Operating Costs per Barrel Through Economies of Scale. A significant portion of expenses at the field level are | |
| · | Large Oil Reserves in Place and Relatively Low Exploration Risk. A majority of the |
Our Kansas Properties
The table below summarizes our current Eastern Kansas acreage by project name as of MarchDecember 31, 2009.
| Project Name | Developed Acreage | Undeveloped Acreage | Total Acreage | |||||||||||||||||||||
| Gross | Net(1) | Gross | Net(1) | Gross | Net(1) | |||||||||||||||||||
| Black Oaks Project | 550 | 522 | 1,850 | 1,758 | 2,400 | 2,280 | ||||||||||||||||||
| Thoren Project | 135 | 135 | 591 | 591 | 726 | 726 | ||||||||||||||||||
| DD Energy Project | 400 | 400 | 1,370 | 1,370 | 1,770 | 1,770 | ||||||||||||||||||
| Tri-County Project | 610 | 606 | 652 | 651 | 1,262 | 1,257 | ||||||||||||||||||
| Gas City Project | 600 | 600 | 4,713 | 4,713 | 5,313 | 5,313 | ||||||||||||||||||
| Total | 2,295 | 2,263 | 9,176 | 9,083 | 11,471 | 11,346 | ||||||||||||||||||
| Project Name | Developed Acreage | Undeveloped Acreage | Total Acreage | |||||||||||||||||||||
| Gross | Net (1) | Gross | Net (1) | Gross | Net (1) | |||||||||||||||||||
| Mississippian Project | 2,840 | 2,556 | 0 | 0 | 2,840 | 2,556 | ||||||||||||||||||
| Cherokee Project | 2,419 | 1,680 | 7,875 | 7,050 | 10,293 | 8,730 | ||||||||||||||||||
| Other | 584 | 584 | 00 | 00 | 584 | 584 | ||||||||||||||||||
| Total | 5,843 | 4,820 | 7,875 | 7,050 | 13,717 | 11,870 | ||||||||||||||||||
| (1) | Net acreage is based on our net working interest as of |
Mississippian Project
Our Mississippian Project encompasses approximately 2,400 gross acresis located in Woodson and Greenwood Counties in Southeast Kansas, whichwhere we owned a 90% working interest in 2,840 gross acres as of December 31, 2012. All of the leases in this project are currently held-by-production. In addition, we acquired an additional 3,530 gross acres (2,711 net acres) in this project at the timeend of acquisition had2012. Our Mississippian Project is currently producing approximately 35 oil wells producing an average of approximately 32200 gross barrels of oil per day or BOPD.
Cherokee Project
Our Cherokee Project is located in Miami and Franklin Counties in Eastern Kansas, where we owned an average rateworking interest of 85% in 10,293 gross acres as of December 31, 2012. As of December 31, 2012, approximately 24% of our acreage position in the Cherokee project was held by production, and numerous low risk development opportunities exist on acreage that is currently undeveloped. Our Cherokee Project is currently producing approximately 250 gross barrels of oil per day from the Squirrel formation at a depth of approximately 50600 feet. We completed 35 new oil wells, and 37 new secondary recovery water injection wells in this project during 2013. The Cherokee Project is located in the prolific Paola Rantoul Field, which according to the Kansas Geological Survey has produced approximately 30 million barrels of wateroil and currently produces approximately 1,000 barrels of oil per day.
On December 14, 2011, we entered into an agreement with Viking Energy Partners, LLC and FL Oil Holdings, LLC (together the "Investors"), effective October 1, 2011, in which we formed a general partnership ("Rantoul Partners") for the purpose of owning and developing certain assets in our Cherokee Project. As part of this agreement, (i) EnerJex contributed certain assets to Rantoul Partners in exchange for an 88.25% ownership interest in Rantoul Partners, and (ii) the Investors contributed $2.35 million to Rantoul Partners in exchange for an 11.75% ownership interest in Rantoul Partners. The Investors contributed an additional $2.65 million throughout 2012, and the entire $5 million of contributed capital was invested in drilling and completion operations on the Rantoul Partners leases by the end of 2012. On January 24, 2013, all of the general partners mutually agreed to dissolve Rantoul Partners effective December 31, 2012. Working interests in the Rantoul Partners leases were ratably assigned to each general partner upon dissolution of Rantoul Partners, and the working interests that comprised the assets of Rantoul Partners are now governed by a joint operating agreement. We received a 75% working interest in the Rantoul Partners leases upon dissolution.
Other
We own a working interest in approximately 584 acres located in Allen County in Eastern Kansas. This acreage is currently producing approximately 5 gross barrels of oil per day per well. This pilot program was expanded so that by June 2008, we were injecting approximately 200 barrels of water per day (bbls water/day) per well in the initial 5 injection wells. Adjacent oil wells showedand is prospective for increased production from multiple zones.
The Opportunity in South Texas
Technological advances in the oil industry have made great strides over the last decade, especially in the area of drilling and completion technologies, mainly through horizontal drilling and artificial fracture stimulation. Multiple sizeable oil deposits were discovered in South Texas during previous decades, but operators lacked the technology to economically produce oil from these reservoirs at the time of discovery. The availability of modern completion technologies, coupled with the current attractive oil price environment, provides an opportunity for operators to economically produce oil from reservoirs that were discovered in the past but were not fully developed due to technology and economic constraints.
Our Texas Properties
The table below summarizes our current South Texas acreage by project name as of December 31, 2011.
| Project Name | Developed Acreage | Undeveloped Acreage | Total Acreage | |||||||||||||||||||||
| Gross | Net (1) | Gross | Net (1) | Gross | Net (1) | |||||||||||||||||||
| El Toro Project | 458 | 183 | 2,975 | 1,384 | 3,433 | 1,567 | ||||||||||||||||||
| Total | 458 | 183 | 2,975 | 1,384 | 43,433 | 1,567 | ||||||||||||||||||
| (1) | Net acreage is based on our net working interest as of December 31, 2012. |
El Toro Project
Our El Toro Project is located in Atascosa and Frio Counties in South Texas. As of December 31, 2012, we owned a weighted average working interest of 46% in 3,433 gross acres, of which the majority is not currently held-by-production. This project was producing approximately 35 gross barrels of oil per day from the Olmos formation at a depth of approximately 5 BOPD4,500 feet. We did not drill any wells in this project and focused 100% of our capital budget on our Eastern Kansas and Eastern Colorado projects during 2013.
Multiple oil fields surround this project, which combined have produced more than 100 million barrels of oil since the 1950's from the Olmos formation. We believe the El Toro Project acreage was neglected due to 25 BOPD. As of March 31, 2009, we are maintaining the 200 bbls water/day average on the injectionits relatively tight (low permeability) reservoir characteristics. Recent advances in stimulation technology have enabled us to drill and complete new oil wells in the pilot program area. El Toro project with a high degree of success. As evidence of this success, we believe that our first two wells in this project produced approximately 100% more oil during the initial 12 months of production than the best well in a directly adjacent field. This directly adjacent field was developed in the 1950’s and has produced approximately 10 million barrels of oil.
We have seen nocompleted 12 wells in the El Toro Project since 2009. While petrophysical data obtained from these wells has been consistent across the project acreage, production results have been inconsistent. We intend to conduct more testing on additional response onwells that are temporarily shut-in. Production results from the 3 most recent wells completed in this project have been successful, although the costs and time lag associated with drilling and completing them significantly exceeded our expectations. This is a direct result of the high demand and limited supply of services and equipment available in the El Toro Project area as of yet. We are also injecting an average of 100 bbls water/day per well in 4 injection wells adjacentdue to the pilot programrapidly developing Eagle Ford Shale play. As a result of increasing costs in this project area, and are closely monitoring data and activities for any resulting increase in production. Based upon the results of our testing, we expect to continue the development plan, subject to availability of capital. Phase II of the plan contemplates drilling over 25 additional water injection wells and drilling over 20 additional producer wells. Project-wide production was an average of approximately 96 BOPD as of March 31, 2009.
Gross STB(1) | Net STB(2) | PV10(3) (before tax) | ||||||||||
| Proved, Developed Producing | 420,080 | 197,640 | $ | 3,781,690 | ||||||||
| Proved, Developed Non-Producing | 50,440 | 30,450 | $ | 650,430 | ||||||||
| Proved, Undeveloped | 875,300 | 352,370 | $ | 944,100 | ||||||||
| Total Proved | 1,345,820 | 580,460 | $ | 5,376,220 | ||||||||
Our Opportunities in Colorado and Nebraska
Black Raven Energy, Inc., EnerJex’s wholly-owned subsidiary, is currently focused on oil and natural gas development in the Denver-Julesburg (DJ) Basin in Colorado and Nebraska. Its assets are focused in two core projects, both of which are located on trend with emerging unconventional resource plays.
Our Colorado Properties
Adena Field: Black Raven owns a 100% working interest in approximately 18,760 acres located in Morgan County, Colorado covering the Thoren Project for $400,000 from MorMeg. This project, atmajority of Adena Field, which has been held by production since it was unitized by the timeUnion Oil Company of acquisition, contained 240 acresCalifornia (Unocal) in Douglas County, Kansas, with 121956. According to the Colorado Oil and Gas Conservation Commission, Adena is the third largest oil wells producing an averagefield in the history of approximately 10 BOPD, 4 water injection wells,Colorado behind Rangely and one water supply well. We have leased an additional 486 acres increasing the total acreageWattenberg, having produced 75 million barrels of this project to 726 acres.
Gross STB(1) | Net STB(2) | PV10(3) (before tax) | ||||||||||
| Proved, Developed Producing | 48,030 | 24,600 | $ | 539,510 | ||||||||
| Proved, Developed Non-Producing | 24,920 | 7,690 | $ | 146,490 | ||||||||
| Proved, Undeveloped | 43,020 | 37,640 | $ | 85,970 | ||||||||
| Total Proved | 115,970 | 69,930 | $ | 771,970 | ||||||||
Gross STB(1) | Net STB(2) | PV10(3) (before tax) | ||||||||||
| Proved, Developed Producing | 75,510 | 64,700 | $ | 972,220 | ||||||||
| Proved, Developed Non-Producing | 23,070 | 19,470 | $ | 183,090 | ||||||||
| Proved, Undeveloped | 39,390 | 31,840 | $ | 85,030 | ||||||||
| Total Proved | 137,970 | 116,010 | $ | 1,240,340 | ||||||||
Black Raven currently produces approximately 20 wells in this project. We have also acquired additional leases, bringing the total project to approximately 1,300 acres.
Gross STB(1) | Net STB(2) | PV10(3) (before tax) | ||||||||||
| Proved, Developed Producing | 177,560 | 141,330 | $ | 1,369,700 | ||||||||
| Proved, Developed Non-Producing | 48,190 | 37,940 | $ | 479,270 | ||||||||
| Proved, Undeveloped | 474,210 | 380,030 | $ | 1,361,430 | ||||||||
| Total Proved | 699,960 | 559,300 | $ | 3,210,400 | ||||||||
Gross STB(1) | Net STB(2) | Gross MCF(3) | Net MCF(4) | PV10(5) (before tax) | ||||||||||||||||
| Proved, Developed Producing | 1,400 | 1,150 | - | - | $ | 28,430 | ||||||||||||||
| Proved, Developed Non-Producing | - | - | - | - | $ | - | ||||||||||||||
| Proved, Undeveloped | 11,850 | 9,780 | - | - | $ | 1,970 | ||||||||||||||
| Total Proved | 13,250 | 10,930 | - | - | $ | 30,400 | ||||||||||||||
Black Raven’s working interest in its Adena Field acreage is subject to a 30% reversionary working interest that will be assigned to an unrelated third party, subject to the terms and conditions of such agreement, after payout of all acquisition, operating, development, and financing costs including interest. The payout balance associated with this reversionary working interest is estimated to be approximately $28 million. The impact of this reversionary working interest has not been factored into Black Raven’s reserve estimates as of June 30, 2013.
Our Nebraska Properties
Niobrara Project: Black Raven owns leases that have existingcovering approximately 50,000 net acres primarily located in Phillips and Sedgwick Counties, Colorado and Perkins County, Nebraska, of which approximately 25,000 acres are held by production and cash flow. Once acquired, subjectmore than 15,000 acres expire after 2015. Black Raven currently produces approximately 250 thousand cubic feet (MCF) of natural gas per day from the Niobrara formation in this project, the majority of which is attributable to availability of capital, we strive to implement an accelerated development program utilizing capital resources, a regional operating focus, an experienced management and technical team, and enhanced recovery technologies to attempt to increase production and increase returns for our stockholders. Our6% overriding royalty interest that it owns in approximately 200 wells that were drilled during the past few years by a large independent oil and natural gas company.
Black Raven's Niobrara acreage was high-graded based on structural features identified through analysis of 114 miles of 2D and 165 square miles (105,000 acres) of 3D seismic data on its original position of 330,000 net acres. The company has identified more than 150 high-ranked Niobrara drilling locations on its existing acreage based on 3D seismic analysis which has historically yielded success rates of approximately 90% in this play. Black Raven's acreage is well situated with direct access to the Cheyenne Hub market and immediate proximity to the 1,679-mile Rocky Mountain Express pipeline and the 436-mile Trailblazer pipeline.
Our Business Strategy
Our principal strategy focuses on the acquisition and development activitiesof shallow oil properties that have low production decline rates and offer abundant drilling opportunities with low risk profiles. We are currently focusedfocusing our oil operations in Eastern Kansas. DependingKansas, Eastern Colorado, South Texas and Nebraska with a near term focus on availabilityEastern Kansas and Eastern Colorado due to what we believe are temporary constraints of capital,services and other restraints, our goal is to increase stockholder value by finding andequipment in South Texas as a result of the rapidly developing oil and natural gas reserves at costs that provide an attractive rate of return on our investments.Eagle Ford Shale play. The principal elements of our business strategy are:
| ·· | Develop Our Existing Properties. |
| ·· | Maximize Operational Control. We seek to operate |
| ·· | Pursue Selective Acquisitions and Joint Ventures. |
| ·· | Reduce Unit Costs Through Economies of Scale and Efficient Operations. As we increase our oil production and develop our existing properties, we expect that our unit cost structure will benefit from economies of scale. In particular, we anticipate reducing unit costs by greater utilization of our existing infrastructure over a larger number of wells. |
| · | Unconventional Oil Resource Potential. Our Adena Field and Niobrara projects are both located on trend with emerging unconventional oil resource plays that are reportedly being pursued by a number of independent oil and gas companies including Southwestern Energy, Devon Energy, Apache Corp, Chesapeake Energy, Wiepking-Fullerton Energy, Cascade Petroleum, Nighthawk Energy, Synergy Resources, Vecta Oil & Gas, Omimex Petroleum, and Recovery Energy. Numerous exploration wells have recently been permitted, drilled, and tested in the DJ basin of Colorado and Nebraska targeting unconventional oil production from Paleozoic (Permian-Pennsylvanian and Mississippian) carbonates and shales. Primary targets include the Marmaton, Cherokee, Morrow, Atoka, Virgil, and Admire formations. We are closely monitoring industry activity in this area and while we believe that our acreage is prospective for commercial oil production from the formations identified above, there can be no certainty that producing oil from any of these formations will ultimately be economically viable on all or any portion of our acreage. |
We are continually evaluatingevaluate new oil and natural gas opportunities in Eastern Kansas, Eastern Colorado, and are also in various stages of discussions with potentialSouth Texas and plan to evaluate joint venture (“JV”)opportunities with partners who would contribute capital and or operational expertise to develop leases that we currently own or would acquire for the JV. Subsequent to year-end (in June 2009), we entered into one such opportunity on the Brownrigg lease in Linn County, Kansas, as discussed above.part of a joint venture arrangement. This economic strategy is anticipated to allow us to utilize our own financial assets toward the growth of our leased acreage holdings, pursue the acquisition of strategic oil and natural gas producing properties or companies and generally expand our existing operations while further diversifying risk. Subject to availability of capital, we plan to continue to bring potential acquisition and JV opportunities to various financial partners for evaluation and funding options. It is our vision to grow the business in a disciplined and well-planned manner.
Our future financial results will continue to depend on: (i) our ability to source and screen potential projects; (ii) our ability to discover commercial quantities of natural gas and oil; (iii) the market price for oil and natural gas; and (iv) our ability to fully implement our exploration, work-over and development program, which is in part dependent on the availability of capital resources. There can be no assurance
| ·· | our ability to source and evaluate potential projects; | |
| ·· | our ability to discover commercial quantities of oil; | |
| ·· | the market price for oil; | |
| ·· | our ability to implement our exploration and development program, which is in part dependent on the availability of capital resources; and | |
| ·· | our ability to cost effectively manage our operations. |
We cannot guarantee that we will be successfulsucceed in any of these respects, thatrespects. Further, we cannot know if the pricesprice of crude oil and natural gas prevailing at the time of production will be at a level allowing for profitable production, or that we will be able to obtain additional funding at terms favorable to us to increase our currently limited capital resources. For a detailed description of these and other factors that could materially impact actual results, please see “Risk Factors” in this document.
Our board of directors has implemented a crude oil and natural gas hedging strategy that will allow management to hedge up to 80%the majority of our net production to mitigate a majority of our exposure to changing oil prices in the intermediate term.
Drilling Activity
The following table sets forth the results of our drilling activities, including both oil production and water injection wells that were drilled and completed during the 2007, 2008year ended December 31, 2012, and 2009 fiscal years.
| Drilling Activity | ||||||||||||||||||||||||
| Gross Wells | Net Wells(1) | |||||||||||||||||||||||
| Fiscal Year | Total | Producing | Dry | Total | Producing | Dry | ||||||||||||||||||
| 2007 Exploratory | -0- | -0- | -0- | -0- | -0- | -0- | ||||||||||||||||||
| 2008 Exploratory | 10 | 10 | -0- | 10 | 10 | -0- | ||||||||||||||||||
2009 Exploratory(2) | 12 | 12 | -0- | 12 | 12 | -0- | ||||||||||||||||||
| 2007 Development | -0- | -0- | -0- | -0- | -0- | -0- | ||||||||||||||||||
| 2008 Development | 59 | 57 | 2 | 58 | 56 | 2 | ||||||||||||||||||
| 2009 Development | 96 | 95 | 1 | 96 | 95 | 1 | ||||||||||||||||||
| Drilling Activity | ||||||||||||||||||||||||
| Gross Wells | Net Wells | |||||||||||||||||||||||
| Fiscal Year | Total | Successful | Dry | Total | Successful | Dry | ||||||||||||||||||
| 2011 – Exploratory | 6 | 0 | 6 | 3.4 | 0 | 3.4 | ||||||||||||||||||
| 2012 – Exploratory | -2- | -0- | -2- | -1.8- | -0- | -1.8- | ||||||||||||||||||
| 2011 – Development | 97 | 97 | 0 | 79.3 | 79.3 | 0 | ||||||||||||||||||
| 2012 – Development | 227 | 226 | 1 | 172.6 | 171.7 | 0.9 | ||||||||||||||||||
| (1) | Net wells are based on our net working interest |
Net Production, Average Sales Price and Average Production and Lifting Costs
The table below sets forth our net oil and natural gas production (net of all royalties, overriding royalties and production due to others) for the fiscal years ended MarchDecember 31, 20092012, and 2008 and 2007,2011, the average sales prices, average production costs and direct lifting costs per unit of production.
Fiscal Year Ended March 31, 2009 | Fiscal Year Ended March 31, 2008 | Fiscal Year Ended March 31,2007 | ||||||||||
| Net Production | ||||||||||||
| Oil (Bbl) | 74,289 | 43,697 | -0- | |||||||||
| Natural gas (Mcf) | 12,275 | 17,762 | 19,254 | |||||||||
| Average Sales Prices | ||||||||||||
| Oil (per Bbl) | $ | 85.67 | $ | 79.71 | $ | -0- | ||||||
| Natural gas (per Mcf) | $ | 5.57 | $ | 6.20 | $ | 4.72 | ||||||
Average Production Cost (1) | ||||||||||||
| Per Bbl of oil | $ | 45.01 | $ | 56.65 | $ | -0- | ||||||
| Per Mcf of natural gas | $ | 15.11 | $ | 13.12 | $ | 9.55 | ||||||
Average Lifting Costs (2) | ||||||||||||
| Per Bbl of oil | $ | 33.01 | $ | 37.08 | $ | -0- | ||||||
| Per Mcf of natural gas | $ | 15.11 | $ | 9.86 | $ | 8.95 | ||||||
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | |||||||
| Net Production | ||||||||
| Oil (Bbl) | 96,842 | 71,729 | ||||||
| Average Sales Prices | ||||||||
| Per Bbl of oil | $ | 87.74 | $ | 87.63 | ||||
| Average Production Cost | ||||||||
| Per Bbl of oil | $ | 47.95 | $ | 63.77 | ||||
| Average Lifting Costs | ||||||||
| Per Bbl of oil | $ | 32.03 | $ | 47.96 | ||||
Production costs include all operating expenses, depreciation, depletion and amortization, lease operating expenses (including price a price differentials) and all associated taxes. Impairment of oil properties is not included in production costs.
Direct lifting costs do not include impairment expense or depreciation, depletion and amortization, but does include transportation costs, which is paid to our purchaser as a price differential.
The table below sets forth our net oil production (net of all royalties, overriding royalties and production due to others), the average sales prices, average production costs and direct lifting costs per unit of production for the periods ended June 30, 2013 and June 30, 2012.
| For the Three Months Ended | For the Six Months Ended | |||||||||||||||
| June 30, | June 30, | |||||||||||||||
| 2013 | 2012 | 2013 | 2012 | |||||||||||||
| Net Production | 23,857 | 23,464 | 50,394 | 42,949 | ||||||||||||
| Oil (Bbl) | ||||||||||||||||
| Average Sales Prices | ||||||||||||||||
| Oil (per Bbl) | $ | 92.08 | $ | 87.33 | $ | 89.97 | $ | 89.94 | ||||||||
| Average Production Cost (1) | ||||||||||||||||
| Per Bbl of oil | $ | 49.06 | $ | 49.16 | $ | 47.57 | $ | 50.88 | ||||||||
| Average Lifting Costs (2) | ||||||||||||||||
| Per Bbl of oil | $ | 31.52 | $ | 31.77 | $ | 30.44 | $ | 31.54 | ||||||||
| (1) | Production costs include all operating expenses, depreciation, depletion and amortization, lease operating expenses and all associated taxes. Impairment of oil |
| (2) | Direct lifting costs do not include impairment expense or depreciation, depletion and amortization. |
Results of Oil and Natural Gas Producing Activities
The following table shows the results of operations from our oil and natural gas producing activities from fiscalthe years ended MarchDecember 31, 2007 through March 31, 2009.2012, and 2011. Results of operations from these activities have been determined using historical revenues, production costs, depreciation, depletion and amortization of the capitalized costs subject to amortization. General and administrative expenses and interest expense have been excluded from this determination.
For the Fiscal Year Ended March 31, 2009 | For the Fiscal Year Ended March 31, 2008 | For the Fiscal Year Ended March 31, 2007 | ||||||||||
| Production revenues | $ | 6,436,805 | $ | 3,602,798 | $ | 90,800 | ||||||
| Production costs | (2,637,333 | ) | (1,795,188 | ) | (172,417 | ) | ||||||
| Depreciation, depletion and amortization | (872,230 | ) | (913,224 | ) | (11,477 | ) | ||||||
| Results of operations for producing activities | $ | 2,972,242 | $ | 894,386 | $ | (93,094 | ) | |||||
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | |||||||
| Production revenues | $ | 8,496,519 | $ | 6,285,411 | ||||
| Production costs | (3,102,321 | ) | (3,440,228 | ) | ||||
| Depreciation, depletion and amortization | (1,541,069 | ) | (1,128,712 | ) | ||||
| Results of operations for producing activities | $ | 3,853,129 | $ | 1,716,471 | ||||
Results of Operations for the Three and Nine Months Ended September 30, 2013 and 2012 compared.
Income :
| Three Months Ended | Increase / | Nine Months Ended | Increase / | |||||||||||||||||||||
| September 30, | (Decrease) | September 30, | (Decrease) | |||||||||||||||||||||
| 2013 | 2012 | $ | 2013 | 2012 | $ | |||||||||||||||||||
| Oil revenues | $ | 2,694,506 | $ | 252,681 | $ | 441,825 | $ | 7,228,543 | $ | 6,204,738 | $ | 1,023,805 | ||||||||||||
Expenses:
| Three Months Ended | Increase / | Nine Months Ended | Increase / | |||||||||||||||||||||
| September 30, | (Decrease) | September 30, | (Decrease) | |||||||||||||||||||||
| 2013 | 2012 | $ | 2013 | 2012 | $ | |||||||||||||||||||
| Production expenses: | ||||||||||||||||||||||||
| Direct operating costs | $ | 916,567 | $ | 807,887 | $ | 108,680 | $ | 2,450,596 | $ | 2,162,470 | $ | 288,126 | ||||||||||||
| Depreciation, depletion and amortization | 484,478 | 459,815 | 24,663 | 1,347,576 | 1,290,334 | 32,579 | ||||||||||||||||||
| Total production expenses | 1,401,045 | 1,267,702 | 133,343 | 3,798,172 | 3,452,804 | 345,368 | ||||||||||||||||||
| General expenses: | ||||||||||||||||||||||||
| Professional fees | 264,050 | 364,519 | (100,469 | ) | 889,529 | 1,037,248 | (147,719 | ) | ||||||||||||||||
| Salaries | 138,875 | 112,370 | 26,505 | 570,864 | 355,750 | 215,114 | ||||||||||||||||||
| Administrative expense | 220,693 | 152,117 | (68,576 | ) | 534,340 | 598,043 | (63,703 | ) | ||||||||||||||||
| Total general expenses | 623,618 | 629,006 | (21,806 | ) | 1,994,733 | 1,991,041 | 3,692 | |||||||||||||||||
| Total production and general expenses | 2,024,663 | 1,896,708 | (5,388 | ) | 5,792,905 | 5,443,845 | 349,060 | |||||||||||||||||
| Income from operations | 669,843 | 355,973 | (127,955 | ) | 792,905 | 760,893 | 674,745 | |||||||||||||||||
| Other income (expense) | ||||||||||||||||||||||||
| Interest expense | (137,831 | ) | (120,922 | ) | (16,909 | ) | (193,204 | ) | (258,529 | ) | (134,675 | ) | ||||||||||||
| Gain on derivatives | (1,160,374 | ) | (1,529,127 | ) | (368,753 | ) | (992,556 | ) | 161,353 | (1,153,909 | ) | |||||||||||||
| Other income | 48,460 | (1,973 | ) | 10,433 | 66,841 | 20,278 | 46,563 | |||||||||||||||||
| Total other income (expense) | (1,289,745 | ) | (1,652,022 | ) | (362,277 | ) | (1,318,919 | ) | (76,898 | ) | (1,242,021 | ) | ||||||||||||
| Net income | $ | (619,902 | ) | $ | (1,296,049 | ) | $ | (676,147 | ) | $ | 116,719 | $ | 683,995 | $ | (567,276 | ) | ||||||||
Active Wells
The following table sets forth the number of productivewells that were actively producing oil and natural gas wellsor injecting water in which we owned an interest as of MarchDecember 31, 2009.
| Producing | ||||||||||||||||
| Project | Gross Oil | Net Oil(1) | Gross Natural Gas | Net Natural Gas(1) | ||||||||||||
| Black Oaks Project | 62 | 59 | -0- | -0- | ||||||||||||
| Thoren Project | 33 | 33 | -0- | -0- | ||||||||||||
| DD Energy Project | 114 | 114 | -0- | -0- | ||||||||||||
| Tri-County Project | 170 | 170 | -0- | -0- | ||||||||||||
| Gas City Project | -0- | -0- | 22 | 22 | ||||||||||||
| Total | 379 | 376 | 22 | 22 | ||||||||||||
| Active | ||||||||
| Project | Gross Oil | Net Oil(1) | ||||||
| El Toro Project | 12 | 4.8 | ||||||
| Mississippian Project | 173 | 155.7 | ||||||
| Cherokee Project | 552 | 410.5 | ||||||
| Other | 125 | 109.8 | ||||||
| Total | 862 | 680.8 | ||||||
| (1) | Net wells are based on our net working interest as of |
Reserves
Proved Reserves (not including Black Raven)
Our estimated total proved PV10 (present value) before tax of reserves as of MarchDecember 31, 20092012, was $10.63$60.8 million, versus $39.6$53.2 million as of MarchDecember 31, 2008. Though2011. Of the 2.9 million net barrels of total proved reserves were comparable at MarchDecember 31, 2009 and 2008; 1.3 million and 1.4 million barrels of oil equivalent (BOE), respectively, the PV10 declined dramatically due to the estimated average price of oil at March 31, 2009 of $42.65 versus $94.53 at March 31, 2008. Of the 1.3 million BOE at March 31, 20092012, approximately 39%53% are classified as proved developed and approximately 61%43% are classified as proved undeveloped. The proved developed reserves consist of proved developed producing (82%) and proved developed non-producing (18%). See “Glossary” on page 77 for our definition of PV10.
Based on an estimatedaverage net oil price of $42.65 as of March 31, 2009,$84.21 per barrel, and applying an annual discount rate of 10% ofto the future net cash flow, the estimated PV10 of the 1.32.9 million BOE,barrels, before tax, is calculated as set forth in the following table:
Summary of Proved Oil and Natural Gas Reserves
as of MarchDecember 31, 2009
Proved Reserves Category | Gross STB(1) | Net STB(2) | Gross MCF(3) | Net MCF(4) | PV10(5) (before tax) | |||||||||||||||
| Proved, Developed Producing | 722,590 | 429,420 | - | - | $ | 6,691,550 | ||||||||||||||
| Proved, Developed Non-Producing | 146,620 | 95,560 | - | - | 1,459,280 | |||||||||||||||
| Proved, Undeveloped | 1,440,760 | 811,650 | - | - | 2,478,510 | |||||||||||||||
| Total Proved | 2,309,970 | 1,336,630 | - | - | $ | 10,629,340 | ||||||||||||||
Proved Reserves Category | Gross STB (1) | Net STB (2) | PV10 (before tax) | |||||||||
| Proved, Developed Producing | 2,398,400 | 1,546,300 | $ | 34,737,900 | ||||||||
| Proved, Undeveloped | 1,951,600 | 1,380,800 | $ | 26,108,400 | ||||||||
| Total Proved | 4,350,000 | 2,927,100 | $ | 60,846,300 | ||||||||
| STB = one stock-tank barrel. |
| Net STB is based upon our net revenue interest, including any applicable reversionary interest. |
Black Raven Proved Reserves
Summary of Oil and Gas Reserves
as of June 30, 2013
Proved Reserves Category | Gross STB(1) (3) | Net STB(2) (3) | PV10 (before tax) | |||||||||
| Proved, Developed Producing | 1,299,767 | 759,517 | $ | 12,082,400 | ||||||||
| Proved, Developed Not Producing | 1,358,150 | 1,030,067 | $ | 11,951,400 | ||||||||
| Proved, Undeveloped | 823,333 | 676,650 | $ | 4,755,400 | ||||||||
| Total Proved | 3,481,250 | 2,466,233 | $ | 28,789,200 | ||||||||
| Probable | 4,487,517 | 3,702,983 | $ | 43,204,951 | ||||||||
| Possible | 9,228,267 | 7,629,200 | $ | 73,625,849 | ||||||||
| Grand Total | 17,197,033 | 13,798,417 | $ | 145,620,000 | ||||||||
| Net | ||
| (3) | Natural gas reserves |
Black Raven’s total net proved oil and Natural Gasnatural gas reserves as of June 30, 2013, were 2.5 million barrels of oil equivalent (47% oil). “Barrels of oil equivalent” means the oil equivalent of natural gas based on a conversion ratio of 6 thousand cubic feet (Mcf) of natural gas to 1 barrel (Bbl) of oil. Approximately 31% of the total proved reserves are classified as proved developed producing, approximately 42% are classified as proved developed non-producing, and approximately 27% are classified as proved undeveloped. The total PV10 (present value) of Black Raven’s proved reserves as of June 30, 2013, was approximately $28.8 million.
Black Raven’s total net probable oil and natural gas reserves as of June 30, 2013, were 3.7 million barrels of oil equivalent (27% oil). The total PV10 (present value) of the probable reserves as of June 30, 2013, was approximately $43.2 million.
Black Raven’s total net possible oil and natural gas reserves as of June 30, 2013, were 7.6 million barrels of oil equivalent (13% oil). The total PV10 (present value) of the possible reserves as of June 30, 2013, was approximately $73.6 million.
Oil Reserves Reported to Other Agencies
We did not file any estimates of total proved net oil or natural gas reserves with, or include such information in reports to any federal authority or agency, other than the SEC, during the fiscal year ended MarchDecember 31, 2009.
Title to Properties
We believe that we have satisfactory title to or rights in all of our producing properties. As is customary in the natural gas and oil industry, minimal investigation of title is made at the time of acquisition of undeveloped properties. In most cases, we investigate title and obtain title opinions from counsel or have title reviewed by professional landmen only when we acquire producing properties or before we begin drilling operations. However, any acquisition of producing properties without obtaining title opinions are subject to a greater risk of title defects.
Our properties are subject to customary royalty interests, liens under indebtedness, liens incident to operating agreements and liens for current taxes and other burdens, including mineral encumbrances and restrictions. Further, our debt is secured by liens substantially on all of our assets. These burdens have not materially interfered with the use of our properties in the operation of our business to date, though there can be no assurance that such burdens will not materially impact our operations in the future.
Sale of Natural Gas and Oil
We do not intend to refine our natural gas or oil production. We expect to sell all or most of our production to a small number of purchasers in a manner consistent with industry practices at prevailing rates by means of long-term and short-term sales contracts, some of which may have fixed price components. In 2013, we sold oil to Coffeyville Resources, Plains Marketing LP, and Sunoco, Inc. on a month-to-month basis (i.e., without a long-term contract). We also have an ISDA master agreement and twoa fixed price swapsswap with BP beginning October 1, 2009 through December 31, 2013.2015. Under current conditions, we should be able to find other purchasers, if needed. All of our produced oil is held in tank batteries. Each respective purchaser picks up the oil from our tank batteries and then each respective purchaser transports the oilit by truck to the refinery.refineries. In addition, our board of directors has implemented a crude oil and natural gas hedging strategy that will allow management to hedge up to 80%the majority of our net production in an effort to mitigate a majority of our exposure to changing oil prices in the intermediate term.
Secondary Recovery and Other Production Enhancement Strategies
When an oil field is first produced, the oil typically is recovered as a result of natural pressure within the producing formation, often assisted by pumps of various types. The only natural force present to move the crude oil to the wellbore is the pressure differential between the higher pressure in the formation and the lower pressure in the wellbore. At the same time, there are many factors that act to impede the flow of crude oil, depending on the nature of the formation and fluid properties, such as pressure, permeability, viscosity and water saturation. This stage of production is referred to as “primary production"primary production",” which in Eastern Kansas normallytypically only recovers up5% to 15% of the crude oil originally in place in a producing formation.
Production from oil fields are amenable to assistance from a waterflood, a formcan often be enhanced through the implementation of “secondary recovery"secondary recovery",” also known as waterflooding, which is useda method in which water is injected into the reservoir through injector wells in order to maintain or increase reservoir pressure and to help sweeppush oil to the wellbore. In a waterflood, certain wells are used to inject water into the reservoir while other wells are used to recover the oil in place.adjacent producing wellbores. We utilize waterflooding as a secondary recovery technique for the majority of our oil field projects.
As thea waterflood matures over time, the fluid produced contains increasing amounts of water and decreasing amounts of oil. Surface equipment is used to separate the produced oil from the water, with the oil going to holding tanks for sale and the water being recycled tore-injected into the injection facilities. In the Black Oaks Project, we realized an initial increase of approximately 20 barrels per day in oil production as a result of the waterflood pilot program.
In addition, we may utilize 3-D3D seismic analysis, horizontal drilling, and other technologies and production techniques to improve drilling results and oil recovery, and to ultimately enhance our production and returns. We also believe use of such technologies and production techniques in exploring for, developing, and exploiting oil and natural gas properties will help us reduce drilling risks, lower finding costs and provide for more efficient production of oil and natural gas from our properties.
Markets and Marketing
The natural gas and oil industry has experienced dramatic price volatility in recent years, and especially in recent months.years. As a commodity, global natural gas and oil prices respond to macro-economic factors affecting supply and demand. In particular, world oil prices have risen and fallen in response to political unrest and supply uncertainty in the United States, Iraq, Venezuela, Nigeria, Russia and Iran,Middle East, and changing demand for energy in rapidly growing economies, notably India and China. North American prospects have become more attractive as oil prices have risen and as efforts to stimulate the US economy and reduce dependence on foreign oil increase.have increased. Escalating conflicts in the Middle East and the ability of OPEC to control supply and pricing are some of the factors impacting the availability of global supply. The costs of steel and other products used to construct drilling rigs and pipeline infrastructure, as well as drilling and well-servicing rig rates, are impacted by the commodity price volatility.
Our market is affected by many factors beyond our control, such as the availability of other domestic production, commodity prices, the proximity and capacity of natural gas and oil pipelines, and general fluctuations of global and domestic supply and demand. We have currently entered into two month-to-month sales contracts (with Coffeyvillewith Coffeeville Resources, Plains Marketing LP, and BP) at this time,Sunoco, Inc., and we do not anticipate difficulty in finding additional sales opportunities, as and when needed.
Oil sales prices are negotiated based on factors such as the spot price for natural gas or posted price for oil, price regulations, regional price variations, hydrocarbon quality, distances from wells to pipelines, well pressure, and estimated reserves. Many of these factors are outside our control. Natural gas and oilOil prices have historically experienced high volatility, related in part to ever-changing perceptions within the industry of future supply and demand.
Competition
The natural gas and oil industry is intensely competitive and we must compete against larger companies, that maymost of whom have greater financial and technical resources than we do and substantially more experience in our industry. These competitive advantages may better enable our competitors to sustain the impact of higher exploration and production costs, natural gas and oil price volatility, productivity variances between properties, overall industry cycles and other factors related to our industry. Their advantage may also negatively impact our ability to acquire prospective properties, develop reserves, attract and retain quality personnel and raise capital.
Governmental Regulations
Our oil and natural gas exploration, production and related operations, when developed, are subject to extensive rules and regulations promulgated by federal, state, tribal and local authorities and agencies. For example, some states in which we may operate, including Kansas, require permits for drilling operations, drilling bonds and reports concerning operations andagencies that impose other requirements relating to the exploration and production of oiloil. For example, laws and natural gas. Such states may also have statutes or regulations addressingoften address conservation matters, including provisions for the unitization or pooling of oil and natural gas properties, the establishment of maximum rates of production from wells, and the regulation of spacing, plugging and abandonment of such wells.wells, rates of production, water discharge, prevention of waste, and other matters. Prior to drilling, we are often required to obtain permits for drilling operations, drilling bonds and file reports concerning operations. Failure to comply with any such rules and regulations can result in substantial penalties. Moreover, such stateslaws and regulations may place burdens from previous operations on current lease owners and the burdens couldthat can be significant.
The regulatory burdenpublic attention on the production of oil and natural gas industry will most likely increase the regulatory burden on our industry and increase the cost of doing business, andwhich may affect our profitability. Although we believe we are currently in substantial compliance with all applicable laws and regulations, because such rules and regulations are frequently amended or reinterpreted, we are unable to predict the future cost or impact of complying with such laws. Significant expenditures may be required to comply with governmental laws and regulations and may have a material adverse effect on our financial condition and results of operations.
The price we may receive from the sale of oil and natural gas liquids will be affected by the cost of transporting products to markets. Effective January 1, 1995, FERC implemented regulations establishing an indexing system for transportation rates for oil pipelines, which, generally, would index such rates to inflation, subject to certain conditions and limitations. We are not able to predict with certainty the effect, if any, of these regulations on our intended operations. However, the regulations may increase transportation costs or reduce well head prices for oil and natural gas liquids.
Legal Proceedings
We may become involved in various routine legal proceedings incidental to our business. However, to our knowledge as of the date of this prospectus except as described below there are no material pending legal proceedings to which we are a party or to which any of our property is subject.
On January 23, 2012, we filed a petition seeking recovery of damages arising from breach of contract, legal malpractice, breach of fiduciary duty and fraud in the Circuit Court of Jackson County, Missouri against attorneys Jeffrey T. Haughey, Robert K. Green, and the law firm Husch Blackwell LLP f/k/a Husch Blackwell Sanders, LLC. The petition in this action, EnerJex Resources, Inc., v. Haughey, et al., alleges, among other things, that the defendants violated their fiduciary duties and defrauded us in connection with our stock offering in 2008. The petition alleges economic loss of approximately $50 million and demands judgment for unspecified actual and punitive damages together with repayment of legal fees paid of over $484,000. A trial to hear a portion of this case in the 16th Circuit Court of Jackson County, Missouri, began on December 2, 2013. In that trial, based on its rulings on written motions, the court disallowed our claims for actual and consequential damages for breach of contract and legal malpractice against the defendants. On December 19, 2013, we reached an agreement with the defendants to settle our claims for breach of fiduciary duty and fraud in return for (i) defendants' paying to us the sum of $500,000, which was paid to us in January 2014, and (ii) dismissal of the defendants’ counterclaim of $492,134 and interest on that amount, which will remove this amount from our balance sheet as a liability. In entering into this settlement, the defendants have not admitted liability on any matter related to the claims in the litigation. As part of this settlement, we are now free to appeal the court’s rulings and request from the appellate court authorization to pursue our claims for actual and consequential damages with respect to our claims alleging breach of contract and legal malpractice against the defendants. We currently maintain an office at 27expect to receive a ruling from the appellate court on that appeal during the second half of 2014. There can be no assurance of the outcome of the appellate process, including whether the appellate court will allow us to seek actual and consequential damages for breach of contract and legal malpractice and breach of fiduciary duty, as well as what amount of damages, if any, we may recover.
MANAGEMENT
Directors, Executive Officers and Corporate Woods, Suite 350, 10975 Grandview Drive, Overland Park, Kansas 66210. This space is leased pursuant to a five year lease that expires in August 2013.
The following table sets forth certain information regarding our currentlists the names and ages as of February 13, 2014, and positions of the individuals who serve as directors and executive officers. Our executive officers serve one-year terms.
| Name | ||||||
| Robert G. Watson, Jr. | ||||||
| R. Atticus Lowe | Senior Vice President | |||||
| 64 | ||||||
| Lance W. Helfert | Director | 40 | ||||
Richard Menchaca | Director | 46 | ||||
| Other Executive Officers | ||||||
| Douglas M. Wright | Chief Financial Officer | |||||
Business Experience:
The principal occupation and business experience during the last five years for each of our Directors and Executive Officers are as follows. Such information is based upon information received by us from such persons.
The paragraphs below provide information about each director of EnerJex, including all positions he holds, his principal occupation and business experience for the past five years, and the names of other publicly-held companies of which he currently serves as a director or served as a director during the past five years. EnerJex believes that all of its directors display personal and professional integrity; satisfactory levels of education and/or business experience; broad-based business acumen; an appropriate level of understanding of its business and its industry and other industries relevant to its business; the ability and willingness to devote adequate time to the work of the EnerJex board of directors and its committees; a fit of skills and personality with those of its other directors that helps build a board of directors that is effective, collegial and responsive to the needs of its company; strategic thinking and a willingness to share ideas; a diversity of experiences, expertise and background; and the ability to represent the interests of all of EnerJex stockholders. The information presented below regarding each director also sets forth specific experience, qualifications, attributes and skills that led the EnerJex board of directors to the conclusion that he should serve as a director in light of EnerJex's business and structure.
Robert G. Watson, Jr. Mr. Watson has been ourserved as President, Chief Executive Officer, and ChairmanSecretary since August 15, 2006.December 31, 2010. Prior to joining EnerJex, he co-founded Black Sable Energy, LLC, approximately 5 years ago and served as its Chief Executive Officer. During his tenure at Black Sable, Mr. CochennetWatson was responsible for the company's acquisition and development of two grassroots oil projects in South Texas, both of which were partnered with larger oil and gas companies on a promoted basis. Prior to founding Black Sable, he was a Senior Associate at American Capital, Ltd. (NASDAQ: ACAS), a publicly traded private equity firm and global asset manager with more than $100 billion of total assets under management. Mr. Watson began his career in the Energy Investment Banking Group at CIBC World Markets and subsequently founded and served as the Managing Partner of Centerra Energy Partners, LLC. Mr. Watson's experience in acquiring and developing oil projects, his knowledge of financial markets, and his managerial and leadership abilities that he has demonstrated while serving as the Company's President and Chief Executive Officer and as chief executive officer for Black Sable Energy, LLC, led to the board's conclusion that he should serve as a director.
R. Atticus Lowe. Mr. Lowe has served as Senior Vice President of CSC Group, LLC.Corporate Development since 2011 and as a Director since December 31, 2010. Mr. Cochennet formedLowe is the CSC Group, LLCChief Investment Officer of West Coast Asset Management, Inc., a registered investment advisor that has invested more than $200 million in the oil and gas industry on behalf of its principals and clients since 2000. He formerly served as a director and chairman of the audit committee for Black Raven Energy, Inc., before we acquired Black Raven in September 2013. Mr. Lowe is a CFA charterholder. His experience in business and finance and his experience as a director and chairman of the audit committee of a company in the oil and gas industry led to the board's conclusion that he should serve as a director.
James G. Miller. Mr. Miller has served as a Director since December 31, 2010. Mr. Miller retired in 2002 after serving as the Chief Executive Officer of Utilicorp United, Inc.'s business unit responsible for the company's electricity generation and electric and natural gas transmission and distribution businesses, which served 1.3 million customers in seven mid-continent states. Utilicorp traded on the New York Stock Exchange, and the company was renamed Aquila in 2002. In 2007, Utilicorp's electricity assets in northwest Missouri were acquired by Great Plains Energy Incorporated (NYSE: GXP) for $1.7 billion, and its natural gas properties and other assets were acquired by Black Hills Corporation (NYSE: BKH) for $940 million. Mr. Miller joined Utilicorp in 1989 through its acquisition of Michigan Gas Utilities, for which he supportedserved as the president from 1983 to 1991. Mr. Miller also is a numbermember of clients that included Fortune 500 corporations, international companies, natural gas/electric utilities, outsource service providers,the board of directors of Guardian 8 Holdings. He currently serves as Chairman of The Nature Conservancy, Missouri Chapter, for which he has been a Trustee for the past 12 years. Mr. Miller's experience as a chief executive officer and president, as well as various start up organizations. The services provided included strategic planning, capital formation, corporate development, executive networkinghis experience from serving as a board member, led to the board's conclusion that he should serve as a director.
Lance W. Helfert. Mr. Helfert has served as a Director since December 31, 2010. Mr. Helfert is the President and transaction structuring. From 1985 to 2002, he held several executive positions with UtiliCorp Uniteda co-founder of West Coast Asset Management, Inc. (Aquila)(WCAM), a registered investment advisor located in Kansas City. His responsibilities included finance, administration, operations, human resources, corporate development, natural gas/energy marketing, and managing several new start up operations.Montecito, California. Prior to co-founding WCAM, he managed a portfolio at Wilshire Associates and was involved in a full range of financial strategies at M.L. Stern & Co. Mr. Helfert is a co-author ofThe Entrepreneurial Investor: The Art, Science and Business of Value Investing, a book published by John Wiley & Sons. He has been featured in Kiplinger's Personal Finance, Forbes, Barron's, Fortune Magazine, and the Market Watch for his experience at UtiliCorpunique market prospective. In addition, Mr. Helfert has been a frequent guest commentator on CNBC and the Fox Business networks. Mr. Helfert has also served on the board of directors for Junior Achievement of Southern California and the Tri-Counties Make-A-Wish Foundation. Mr. Helfert's knowledge of the capital markets, coupled with his knowledge and understanding of finance and financial reporting led the board to conclude that he should serve as a director. On December 23, 2013, the United States Securities and Exchange Commission (SEC) entered an order in an administrative proceeding, In the Matter of West Coast Asset Management, Inc., and Lance W. Helfert, File No. 3-15660. In that matter, WCAM and Mr. Cochennet served 6 yearsHelfert, without admitting or denying the allegations, entered into a settlement with the Federal Reserve System.SEC regarding certain negligence-based violations of Section 17(a)(2) of the Securities Act and Sections 206(2) and 206(4) of the Investment Advisers Act of 1940 (the Advisers Act). The matter was based upon an untrue statement made in an email that Mr. Cochennet graduatedHelfert sent, in 2008, to an adviser to a prospective investor in an investment fund that was managed by WCAM. The SEC ordered WCAM and Mr. Helfert to cease and desist from committing or causing further such negligence-based violations, censured them, ordered WCAM to disgorge certain fees, and ordered WCAM and Mr. Helfert each to pay a monetary fine. WCAM and Mr. Helfert timely paid those amounts to the SEC.
Richard Menchaca. Richard Menchaca has been a Director since June 6, 2013. Mr. Menchaca attended the University of Texas at Arlington where he received a BBA in Finance and pursued a MBA in Finance, and received a Graduate Degree from the SMU Southwestern School of Banking. Mr. Menchaca spent 18 years in the corporate banking industry with First Republic Bank (n.k.a. Bank of America), Bank One in Fort Worth and Fuji Bank, and Guaranty Bank in Houston. While at Guaranty Bank, Mr. Menchaca was one of the founding members of the Oil and Gas Banking Group, and within 18 months of its formation became the most profitable lending group within the bank with over $900,000,000 of loans to oil and gas industry. Mr. Menchaca was the principal and founder of Petras Energy, LLC, an oil and gas production company based in Midland, Texas. The company was successfully sold in January 2006. Mr. Menchaca has been the founder and principal of several privately owned oil and gas companies with operations in Texas, Oklahoma and Louisiana. Since May 2010, Mr. Menchaca currently presides as President and Chief Executive Officer of Petroflow Energy Corporation, a Tulsa-based exploration and production company, as well as a member of its board of directors since June 2009. Mr. Menchaca also serves as a director on the board of Fortis Plastics and a non-profit organization based in Houston, Texas.
Douglas M. Wright. Doug has been Chief Financial Officer since August 2012. Mr. Wright served as Corporate Controller and Chief Accounting Officer of Nations Petroleum Company Ltd. from 2006 to August 2012. Prior to Nations, he served as a Manager of Financial Reporting for Noble Energy (contract). In 1996, he founded Fashion Investments Inc. and served as its Chief Executive Officer until 2005. Fashion Investments owned and operated the largest independent commercial laundry facility in Colorado Springs. From 1986 to 1996, Mr. Wright worked for Oryx Energy Company in various capacities including, Manager, Financial Reporting, Manager, Strategic Planning and General Auditor. From 1977 to 1986, he served as a Senior Manager with Deloitte & Touche. Mr. Wright is a Certified Public Accountant and earned his B.A. from the University of Nebraska with a B.A. in FinancePittsburgh and Economics.
CORPORATE GOVERNANCE OF THE COMPANY
Corporate Governance Guidelines
The EnerJex board of directors since May 2007. Effective April 7, 2009, Mr. Wonishhas adopted Corporate Governance Guidelines. A copy of these Corporate Governance Guidelines can be found on the Investors—Corporate Governance section of EnerJex's corporate website at www.enerjex.com. Information contained on EnerJex's website or that can be accessed through EnerJex's website does not constitute a part of this prospectus. EnerJex has included its website addresses only as inactive textual references and does not intend it to be an active link to its website.
Among the topics addressed in EnerJex's Corporate Governance Guidelines are:
| · | Director qualifications; |
| · | Board meetings; |
| · | Director Responsibilities; |
| · | Size of Board; |
| · | Management Succession; |
| · | Orientation and continuing education; |
| · | Annual Performance Evaluation; |
| · | Director Compensation; |
| · | Direct Access to Management and Advisors; and |
| · | Public disclosure of corporate governance policies. |
Director Independence
The EnerJex board of directors has determined that two of the five current directors—James G. Miller and Richard Menchaca—are "independent directors" under the American Stock Exchange Company Guidelines. The American Stock Exchange Company Guidelines provide a non-exclusive list of persons who are not considered independent. For example, under these rules, a director who is, or during the past three years was, appointed President and Chief Operating Officer of Petrodome Energy, LLC, a privately held firm. From December 2004 to June 30, 2007, Mr. Wonish was Vice President of Petroleum Engineers Inc., aemployed by the Company or by any parent or subsidiary of the company, other than prior employment as an interim chairman or chief executive officer, would not be considered independent. No director qualifies as independent unless the EnerJex board of directors affirmatively determines that the director does not have a material relationship with the company that would interfere with the exercise of independent judgment. In making an affirmative determination that a director is an "independent director," the EnerJex board of directors reviewed and discussed information provided by these individuals and by EnerJex with regard to each of their business and personal activities as they may relate to EnerJex and its management.
| 37 |
Board Leadership Structure
The CYMRI Corporation, now CYMRI, L.L.C.,EnerJex board of directors believes that EnerJex stockholders are best served if the EnerJex board of directors retains the flexibility to adapt its leadership structure to applicable facts and circumstances, which necessarily change over time. The EnerJex board of directors believes it is best not to have a wholly-owned subsidiaryfixed policy on this issue and that it should be free to make this determination based on what it believes is best under the circumstances. However, the EnerJex board of Stratum Holdings, Inc. On July 1, 2007, Mr. Wonish was appointed Presidentdirectors strongly endorses the concept of an independent director being in a position of leadership for the rest of the outside directors. Under EnerJex's Corporate Governance Guidelines, if at any time the chief executive officer and Chief Operating Officerchairman of Petroleum Engineers Inc. Mr. Wonish was also Presidentthe board positions are held by the same person, the EnerJex board of CYMRI, L.L.C. Afterdirectors, upon recommendation of the sale of Petroleum Engineers Inc. in March of 2008, Mr. Wonish resigned all positions in Petroleum Engineers Inc.nominating and CYMRI, L.L.C. as well as resigningcorporate governance committee, will elect an independent director as a lead independent director.
Executive Sessions
At each regular meeting of the EnerJex board of directors, the independent directors meet in executive session with no company management present during a portion of the meeting. James G. Miller presides over these executive sessions and serves as a liaison between the independent directors and EnerJex's Chief Executive Officer.
Board Meetings and Attendance
The EnerJex board of directors held 9meetings during 2013. All of EnerJex's directors attended 75 percent or more of the aggregate meetings of the EnerJex board of directors and all committees on which they served during 2013.
Board Committees
The board of directors has an audit committee, and the governance, compensation and nominating committee. Each of these committees operates under a charter that has been previously approved by the EnerJex board of directors and has the composition and responsibilities described below. The board of directors from time to time may establish other committees to facilitate the management of the company and may change the composition and the responsibilities of the existing committees.
The table below summarizes the current membership of each of EnerJex's two standing board committees.
| Director | Audit | Governance, Compensation & Nominating |
| James G. Miller | Chair | X |
| R. Atticus Lowe | X | - |
| Lance W. Helfert | - | X |
| Richard Menchaca | - | Chair |
| Robert G. Watson, Jr. | - | - |
Audit Committee
The primary responsibilities of the audit committee include:
| · | overseeing the combined company's accounting and financial reporting processes, systems of internal control over financial reporting and disclosure controls and procedures on behalf of the board of directors and reporting the results or findings of its oversight activities to the board; |
| · | having sole authority to appoint, retain and oversee the work of our independent registered public accounting firm and establishing the compensation to be paid to the independent registered public accounting firm; |
| · | establishing procedures for the receipt, retention and treatment of complaints regarding accounting, internal accounting controls and/or or auditing matters and for the confidential, anonymous submission by employees of concerns regarding questionable accounting or auditing matters; |
| · | reviewing and pre-approving all audit services and permissible non-audit services to be performed for the Company by its independent registered public accounting firm as provided under the federal securities laws and rules and regulations of the SEC; and |
| · | overseeing our system to monitor and manage risk, and legal and ethical compliance programs, including the establishment and administration (including the grant of any waiver from) a written code of ethics applicable to each of the combined company's principal executive officer, principal financial officer, principal accounting officer or controller, or persons performing similar functions. |
The audit committee will have the authority to engage the services of outside experts and advisors as it deems necessary or appropriate to carry out its duties and responsibilities.
Our audit committee consists of Mr. Miller, Mr. Lowe, and Mr. Menchaca. The board of directors has determined that each anticipated member of the Stratum Holdings, Inc.audit and finance committee will qualify as "independent" for purposes of membership on audit committees pursuant to the American Stock Exchange Company Guidelines and the rules and regulations of the SEC and is "financially literate" as required by the American Stock Exchange Company Guidelines. In addition, the board of directors.directors has determined that Mr. Wonish heldMiller qualifies as an "audit committee financial expert" as defined by the positionrules and regulations of President & Chief Operating Officer of Striker Oil & Gas, Inc. prior to his engagement with Petrodome Energy, LLC.. He previously achieved positions of increasing responsibility with PANACO, Inc., a public oilthe SEC.
Governance, Compensation and natural gas company, ultimately serving as that company’s President and Chief Operating Officer. He began his engineering career at Amoco in 1975 and joined Panaco’s engineering staff in 1992. Mr. Wonish serves as EnerJex’s chairmanNominating Committee
The primary responsibilities of the Governance, Compensation and Nominating Committee include:
| · | recommending to the board of directors for its determination the annual salaries, incentive compensation, long-term incentive compensation, special or supplemental benefits or perquisites and any and all other compensation applicable to our chief executive officer and other executive officers; |
| · | reviewing and making recommendations to the board of directors regarding any revisions to corporate goals and objectives with respect to compensation for the combined company's chief executive officer and other executive officers and establishing and leading a process for the full board of directors to evaluate the performance of our chief executive officer and other executive officers in light of those goals and objectives; |
| · | administering our equity-based compensation plans applicable to any employee of the Company and recommending to the board of directors specific grants of options and other awards for all executive officers and determining specific grants of options and other awards for all other employees, under the combined company's equity-based compensation plans; |
| · | reviewing and discussing with the chief executive officer and reporting periodically to the board of directors plans for executive officer development and corporate succession plans for the chief executive officer and other key executive officers and employees; and |
| · | annually reviewing and discussing with management the "Compensation Discussion and Analysis" section of our proxy statement in connection with our annual meeting of stockholders and based on such review and discussions make a recommendation to the board of directors as to whether the "Compensation Discussion and Analysis" section should be included in our proxy statement in accordance with applicable rules and regulations of the SEC and any other applicable regulatory bodies. |
| · | identifying individuals qualified to become board members; |
| · | recommending director nominees for each annual meeting of the stockholders and director nominees to fill any vacancies that may occur between meetings of stockholders; |
| · | being aware of the best practices in corporate governance and developing and recommending to the board of directors a set of corporate governance standards to govern the board of directors, its committees, the company and its employees in the conduct of the business and affairs of the combined company; |
| · | developing and overseeing the annual board and board committee evaluation process; and |
| · | establishing and leading a process for determination of the compensation applicable to the non-employee directors on the board. |
The governance, compensation and nominating committee has the authority to engage the services of outside experts and is a memberadvisors as it deems necessary or appropriate to carry out its duties and responsibilities.
The governance, compensation and nominating committee consists of Mr. Menchaca, Mr. Miller and Mr. Helfert.
Role of the company’s audit committee. Mr. Wonish received his Mechanical Engineering degree from the University of Missouri-Rolla.
The board of directors since May 2007. Since July 1999, Mr. Dammeyerdoes not have a separate risk oversight body. Instead, the EnerJex board has servedoverall responsibility for risk oversight, including, as Presidentpart of D-Two Solutions through which he supports clients by primarily providing mergerregular board and acquisition support, strategic planning, budgetingcommittee meetings, general oversight of executives’ management of risks relevant to us. In overseeing risks, the board seeks to understand the material risks, including financial, competitive, and forecasting process developmentoperational risks, we face and implementation. From March 1999 through July 1999, Mr. Dammeyer was a Directorthe steps management is taking to manage those risks. It also has the responsibility for understanding what level of International Financial Management for UtiliCorp United Inc. (Aquila), a multinational energy solutions provider in Kansas City, Missouri. From November 1995 through March 1999, Mr. Dammeyer served as the Chief Financial Controller of United Energy Limited in Melbourne, Australia. Mr. Dammeyer also served in numerous management positions at Michigan Energy Resources Company, including Director of Internal Audit. Mr. Dammeyer earned his Bachelor of Business Administration degree, with dual majors in Accounting and Corporate Financial Management fromrisk is appropriate. The University of Toledo, Ohio.
While the full EnerJex board has overall responsibility for risk oversight, the board has delegated oversight responsibility related to certain risks to its two committees. The audit committee, under its charter, has been Presidentdelegated the responsibility of Energy Management Resources, an energy processreviewing and discussing with management firm serving industrialour major financial risk exposures and large commercial companies throughout the U. S.steps that management has taken to monitor and Canada. Mr. Palmercontrol such exposures (including management’s risk assessment and risk management policies). EnerJex's governance, compensation and nominating committee is responsible for considering risks within its areas of responsibility. The board does not believe that our compensation policies encourage excessive risk-taking, as the compensation plans are designed to align its employees with short- and long-term corporate strategy. Generally, our equity awards vest over several years, which the board has 25 yearsdetermined encourages our employees to act with regard to the long term interest of expertiseEnerJex and to focus on sustained stock price appreciation.
The board’s role in risk oversight has not had any effect on the natural gas arena. His experiences encompass a wide areaboard’s leadership structure.
Code of Conduct and Ethics
EnerJex's code of conduct and ethics applies to all of EnerJex's employees, officers and directors, including EnerJex's principal executive officer and principal financial officer, and meets the requirements of the natural gas industrySEC. A copy of EnerJex's code of conduct and include workingethics is filed as an exhibit to EnerJex's annual report on Form 10-KSB for natural gas marketing companies, local distribution companies, and FERC regulated pipelines. Prior to becoming an independent energy consultant in 1997, Mr. Palmer’s last position was Vice President/National Account Salesthe fiscal year ended March 31, 2007.
Policy Regarding Director Attendance at UtiliCorp United Inc. (Aquila)Annual Meetings of Kansas City, Missouri. OverStockholders
It is the years Mr. Palmer has worked in many civic organizations including United Way and has been a Presidentpolicy of the local Kiwanis Club. Junior Achievement of Minnesota awarded him the Bronze Leadership Award for his accomplishments which included being an advisor, program manager, holding various Board positions, and ultimately being Board President.
Complaint Procedures
EnerJex's audit committee has established procedures for the receipt, retention and treatment of complaints received by EnerJex regarding accounting, internal accounting controls, or auditing matters, and the submission by EnerJex's employees, on a confidential and anonymous basis, of concerns regarding questionable accounting or auditing matters. EnerJex's personnel with such concerns are encouraged to discuss their concerns with their supervisor first, who in turn will be responsible for informing EnerJex's chief executive officer of any concerns raised. If an employee prefers not to discuss a particular matter with his or her own supervisor, the employee may instead discuss such matter with EnerJex's chief executive officer. If an individual prefers not to discuss a matter with the chief executive officer or if the chief executive officer is unavailable and the authormatter is urgent, the individual is encouraged to contact the chairman of numerous technical papers alongEnerJex's audit committee, James G. Miller.
Process Regarding Stockholder Communications with a number of patents on seismic technology. He was a co-founder of two seismic technology startups that were later sold to NYSE-listed companies, and he regularly consults for many of the major oil companies including Chevron and BP. In 1998, he founded Berkeley GeoImaging LLC, which has completed five equity private placements for oil and natural gas exploration and development projects. Dr. Rector is a tenured professor of Geophysics at the University of California at Berkeley and a faculty staff scientist at the Lawrence Berkeley National Laboratory. He has been the Editor-in-Chief of the Journal of Applied Geophysics and has also served on the Society of Exploration Geophysicists Executive Committee. He received his Masters and Ph.D. degrees in Geophysics from Stanford University.
EnerJex stockholders may communicate with the EnerJex board of directors currentlyor any one particular director by sending correspondence, addressed to EnerJex's Corporate Secretary, EnerJex Resources, Inc., 4040 Broadway, Suite 508, San Antonio, Texas 78209, with an instruction to forward the communication to the EnerJex board of directors or one or more particular directors. EnerJex's Corporate Secretary will forward promptly all such stockholder communications to the EnerJex board of directors or the one or more particular directors, with the exception of any advertisements, solicitations for periodical or other subscriptions and other similar communications.
Executive Compensation
Compensation Discussion and Analysis
Because we are a "smaller reporting company," as defined by 17 CFR § 229.10(f)(1), we are not required to provide a compensation discussion and analysis in this document. Nevertheless, we provide this Compensation Discussion and Analysis to address the aspects of our compensation programs and explain our compensation philosophy, policies, and practices with respect to our Named Executive Officers that are listed in the "Summary Compensation Table" on page [·]. During fiscal 2013, these individuals were: Robert G. Watson, Jr., our chief executive officer, and Douglas W. Wright, our chief financial officer.
Our compensation program is designed to recruit and retain as executive officers individuals with the highest capacity to develop, grow and manage our business, and to align their compensation with our short-term and long-term goals. To do this, our compensation program for executive officers is made up of the following main components: (i) base salary, designed to compensate our executive officers for work performed during the fiscal year; (ii) short-term incentive programs, designed to reward our executive officers for our yearly performance and for their individual performances during the fiscal year; and (iii) equity-based awards, meant to align our executive officers interests with our long-term performance.
The board has appointed a governance, compensation and nominating committee, which consists of five members. OurJames G. Miller and Lance W. Helfert, to assist the board in discharging its responsibilities relating to compensation matters, including matters relating to compensation programs for directors serve one-year terms. Ourand executive officers. At present, our board of directors has affirmatively determined that Messrs. Wonish, Dammeyer, Palmer and Dr. Rector are independent directors,Mr. Miller is an "independent" director, as defined by Section 803 of the American Stock Exchange Company Guide.
| Name | Fees Earned or Paid in Cash $ | Stock Awards $ | Option Awards (2) $ | All Other Compensation $ | Total $ | |||||||||||||||
| Daran G. Dammeyer | $ | 58,000 | $ | 12,000 | (1) | $ | -0- | $ | -0- | $ | 70,000 | |||||||||
| Darrel G. Palmer | $ | 26,500 | $ | -0- | $ | -0- | $ | 20,000 | (3) | $ | 46,500 | |||||||||
| Robert G. Wonish | $ | 49,000 | $ | -0- | $ | -0- | $ | -0- | $ | 49,000 | ||||||||||
| Dr. James W. Rector | $ | 22,500 | $ | -0- | $ | -0- | $ | -0- | $ | 22,500 | ||||||||||
We structure total compensation for our executives to provide a guaranteed amount of cash compensation in the form of competitive base salaries, while also providing a meaningful amount of annual cash compensation that is at risk and dependent on our performance and individual performances of the boardexecutives, in the form of directors. Thediscretionary annual retainerbonuses. We also seek to provide a portion of total compensation in the form of equity-based awards under our equity plans, in order to align the interests of executives and other key employees with those of our stockholders and for non-employee directors is $20,000 with a meeting feeretention purposes. Historically, we have not made regular annual grants of $1,500awards under our Plan. Going forward, we expect that equity-based awards may be made more regularly and that equity-based awards may become more prominent in our annual compensation decision-making process.
Compensation decisions for those in attendance and $750 for those who participate by telephone. The chairmanindividual executive officers are the result of the auditsubjective analysis of a number of factors, including the individual executive officers experience, skills or tenure with us and changes to the individual executive officers position. In evaluating the contributions of executive officers and our performance, although no pre-determined numerical goals were established, a variety of financial measures have been generally considered, including non-GAAP financial measures used by management to assess our financial performance.
In making individual compensation decisions, the governance, compensation and nominating committee historically has not relied on pre-determined performance goals or targets. Instead, determinations regarding compensation have been the result of the exercise of judgment based on reasonably available information and, to that extent, were discretionary. Each executive officer's current and prior compensation is considered in setting future compensation. The governance, compensation and nominating committee will be paid an annual retainerconsider the amount of $42,000, payable with $2,500 per montheach executive officer's current compensation as a base against which determinations are made as to whether increases are appropriate to retain the executive officer in cashlight of competition or in order to provide continuing performance incentives. Subject to the provisions contained in the executive officer's employment agreement, if any, the governance, compensation and $12,000 worth of common stock. Membersnominating committee has the discretion to adjust any of the auditcomponents of compensation to achieve our goal of recruiting, promoting and retaining as executive officers, individuals with the skills necessary to execute our business strategy and develop, grow and manage our business.
The governance, compensation and nominating committee has historically relied upon the judgment and industry experience of its members in making decisions with respect to total compensation and with respect to the allocation of total compensation among our three main components of compensation. Going forward, we expect that the governance, compensation and nominating committee may make compensation decisions taking into account trends occurring within our industry, including from a peer group of companies. Additionally, we expect that the governance, compensation and nominating committee may take into account trends occurring within a group of publicly traded energy companies with market capitalizations in the same range as our own, including from a peer group of companies.
Base salaries for our executive officers will be paiddetermined annually by an assessment of our overall financial and operating performance, each executive officer's performance evaluation and changes in his or her responsibilities. While many aspects of performance can be measured in financial terms, senior management will also be evaluated in areas of performance that are more subjective. These areas include the development and execution of strategic plans, the exercise of leadership in the development of management and other employees, innovation and improvement in our business activities and each executive officer's involvement in industry groups and in the communities that we serve. We seek to compensate executive officers for their performance throughout the year with annual cash retainerbase salaries that are fair and competitive within our marketplace. We believe that executive officer base salaries should be competitive with salaries for executive officers in similar positions and with similar responsibilities in our marketplace and adjusted for financial and operating performance and each executive officers performance evaluation, length of $15,000service with us and $375 per meeting attended. The chairmanprevious work experience. Individual salaries have historically been established by the governance, compensation and nominating committee based on the general industry knowledge and experience of its members, in alignment with these considerations, to ensure the attraction, development and retention of superior talent. Going forward, we expect that the governance, compensation and nominating committee will be paidcontinue to focus on the above considerations and may also take into account relevant market data, including data from our peer group when determining compensation for EnerJex's executive officers. In 2012, we amended and restated the employment agreement with Robert G. Watson, Jr. and entered into an employment agreement with Douglas M. Wright. In connection with approving the amended and restated employment agreement with Robert G. Watson, Jr., the governance, compensation and nominating committee approved a base salary increases for 2013 for Mr. Watson so that he will receive $225,000 per year rather than $150,000
Executive officers are rewarded for their contribution to our financial and operational success through the award of discretionary annual cash retainerincentive bonuses. Annual cash incentive awards, if any, for the chief executive officer are determined by the governance, compensation and nominating committee.
Long-term incentive compensation in the form of $8,000, payable quarterly, while members ofequity grants are used to provide incentives for performance that committee will be paid an annual cash retainer of $2,000, payable quarterly,leads to enhanced stockholder value, encourage retention and $375 per meeting attended. In addition,closely align the directors are reimbursed for expenses incurred in connectionexecutive officers interests with board and committee membership.
Summary Compensation Table
The following table sets forth summary compensation information for the fiscal years ended MarchDecember 31, 20092013, 2012 and 20082011 for our chief executive officer and our chief financial officer. We did notrefer to our chief executive officer and our chief financial officer as our "Named Executive Officers" elsewhere in this document.
| Name and Principal Position | Fiscal Year | Salary ($) | Bonus(3) ($) | Stock Awards ($) | Option Awards ($) | Nonequity Incentive Plan Compensation ($) | Non- qualified Deferred Compen- sation Earnings ($) | All Other Compensation ($) | Total ($) | |||||||||||||||||||||||||||
| (a) | (b) | (c) | (d) | (e) | (f) | (g) | (h) | (i) | (j) | |||||||||||||||||||||||||||
| Robert G. Watson, Jr., Chief Executive | 2013 | $ | 150,000 | - | - | - | - | - | - | $ | 150,000 | |||||||||||||||||||||||||
| Officer(1) | 2012 | 150,000 | - | - | - | - | - | - | 150,000 | |||||||||||||||||||||||||||
| 2011 | 150,000 | - | - | - | - | - | 150,000 | |||||||||||||||||||||||||||||
| Douglas M. Wright, Chief Financial | 2013 | $ | 150,000 | - | - | - | - | - | - | $ | 140,000 | |||||||||||||||||||||||||
| Officer(2) | 2012 | 140,000 | - | - | 750,000 | (4) | - | - | - | 140,000 | ||||||||||||||||||||||||||
(1) On December 31, 2010, we entered into an employment agreement with Robert G. Watson, Jr. This employment agreement was amended and restated on December 31, 2012. Mr. Watson's employment agreement terminates on December 31, 2014. For each calendar year that Mr. Watson's employment agreement is in effect, he is entitled to a cash bonus subject to him meeting performance criteria that the board of directors deems appropriate. In fiscal year ending December 31, 2012, no bonus was awarded. Mr. Watson has the option to receive health insurance coverage for him and his dependents at the cost and expense of EnerJex or $1,000 per month to reimburse Mr. Watson for an individual health insurance plan. He may also receive fringe benefits that the Board determines are to be provided to our employees generally.
(2) On July 6, 2012, the board unanimously approved an employment offer to Douglas M. Wright. Under the employment agreement, effective as of August 15, 2012, which expires on December 31, 2013, Mr. Wright will have any otherthe potential to earn an annual bonus at the discretion of the board. For each calendar year that Mr. Wright's employment agreement is in effect, he is entitled to a cash bonus subject to him meeting performance criteria that the chief executive officersofficer deems appropriate. In fiscal year ending December 31, 2012, no bonus was awarded. Mr. Wright has the option to receive health insurance coverage for him and his dependents at the cost and expense of us or $1,500 per month to reimburse Mr. Wright for an individual health insurance plan. We will reimburse Mr. Wright for up to $5,000.00 of relocation related expenses incurred by Mr. Wright. He may also receive fringe benefits that the Board determines are to be provided to our employees generally.
(3) We may award discretionary annual bonuses to our named executives for their performance. No bonuses were paid for fiscal 2012.
(4) We have agreed to grant to Mr. Wright an option expiring on July 31, 2017, to purchase 750,000 shares of our common stock at a cash exercise price equal to the fair market value of those shares as of the end of fiscal 2009 whose total compensation exceeded $100,000. We refer to these persons as our named executive officers elsewhere in this prospectus.
| Name and Principal Position | Fiscal Year | Salary ($) | Bonus ($) | Option Awards ($) | All Other Compen- sation ($) | Total ($) | ||||||||||||||||
| C. Stephen Cochennet | 2009 | $ | 186,525 | $ | 50,000 | $ | - | (2) | $ | - | $ | 236,525 | ||||||||||
| President, Chief Executive Officer | 2008 | $ | 156,000 | - | 859,622 | (1) | - | $ | 1,015,622 | |||||||||||||
| Dierdre P. Jones | 2009 | $ | 128,808 | $ | 10,000 | - | (2) | - | $ | 138,808 | ||||||||||||
| Chief Financial Officer | 2008 | - | (3) | - | (3) | - | (3) | - | (3) | - | (3) | |||||||||||
| Option Awards | ||||||||||||||||||||
Fiscal Year | Number of Securities Underlying Unexercised Options Exercisable (#) | Number of Securities Underlying Unexercised Options Unexercisable (#) | Number of Securities Underlying Unexercised Unearned Options (#) | Option Exercise Price ($) | Option Expiration Date | |||||||||||||||
| C. Stephen Cochennet | 2009 | 200,000 | (1) | - | - | $ | 6.25 | 05/03/2011 | ||||||||||||
| Dierdre P. Jones | 2009 | 20,000 | (2) | - | - | $ | 6.30 | 07/31/2011 | ||||||||||||
Equity Compensation Plans
We currently have three equity compensation plans, each of which has been approved by our stockholders. Any outstanding stock options issued under our prior equity compensation plans remain effective in accordance with us ortheir terms. Officers (including officers who are members of the board of directors), directors, employees and consultants are eligible to receive options under our subsidiaries, orstock option plans. The governance, compensation and nominating committee administers the stock option plans and determines those persons to whom options will be granted, the number of options to be granted, the provisions applicable to each grant and the time periods during which the options may be exercised.
Each option granted under the stock option plans will be exercisable for a term of not more than 10 years after the date of grant. Certain other restrictions will apply in connection with the plans when some awards may be exercised. In the event of a change of control (as defined in control, orthe stock option plans), the vesting date on which all options outstanding under the stock option plans may first be exercised will be accelerated. Generally, all options terminate 90 days after a change in the person’s responsibilities following a change inof control.
2000/2001 Stock Option Plan
The boardBoard of directorsDirectors approved theour 2000/2001 Stock Option Plan on September 25, 2000, and our stockholders ratified the plan on September 25, 2000.plan. The entire board of directors administers this plan. The total number of options that can be granted under the plan is 200,000 shares and all such shares were previously granted to Mr.the former chief executive officer, C. Stephen Cochennet. On August 3, 2009, we exchanged these outstanding options for 50,000 shares of our restricted common stock. Therefore, all 200,000 shares reserved for issuance under this plan are available again available for issuance.
Under this plan, only officers, employees and directors who are also employees or any of its subsidiaries will be eligible to receive grants of incentive stock options. Officers, employees and directors (whether or not they are also employees) of EnerJex or any of its subsidiaries, as well as consultants, independent contractors or other service providers by us or any of our subsidiaries will be eligible to receive grants of nonqualified options. Non-qualified stock options will be granted by the board of directors with an option price not less than 85% of the fair market value of the shares of common stock to which the non-qualified stock option relates on the date of grant. In no event may the option price with respect to an incentive stock option granted under the stock option plan be less than the fair market value of such common stock. However the price shall not be less than 110% of the fair market value per share on the date of the grant in the case of an individual then owning more than 10% of the total combined voting power of all classes of stock of the corporation.
Each option granted under the stock option plan will be assigned a time period for exercising not to exceed ten years after the date of the grant. Certain other restrictions will apply in connection with this plan when some awards may be exercised.
Generally, all options under this plan terminate 90 days after a change of control if the option holder is terminated other than for cause.
The 2002-2003 Stock Option Plan/Stock Incentive Plan
The boardBoard of directorsDirectors approved the EnerJex Resources, Inc. Stock Option Plan on August 1, 2002 (the “2002-2003"2002-2003 Stock Option Plan”Plan"). Originally, the total number of options that could be granted under the 2002-2003 Stock Option Plan was not to exceed 400,000 shares. In September 2007, our stockholders approved a proposal to amend and restate the 2002-2003 Stock Option Plan to increase the number of shares issuable to 1,000,000. On October 14, 2008, our stockholders approved a proposal to amend and restate the 2002-2003 Stock Option Plan to (i) rename it the EnerJex Resources, Inc. Stock Incentive Plan (the “Stock"Stock Incentive Plan”Plan"), (ii) increase the maximum number of shares of our common stock that may be issued under the Stock Incentive Plan from 1,000,000 to 1,250,000, and (iii) add restricted stock as an eligible award that can be granted under the Stock Incentive Plan.
General Terms of Plans
Officers (including officers who are members of the board of directors), directors, and other employees and consultants and our subsidiaries (if established) will beare eligible to receive awards under the 2000/20012002-2003 Stock Option Plan and the Stock Incentive Plan. AThe governance, compensation and nominating committee of the board of directors will administer theadministers these plans and will determinedetermines those persons to whom awards will be granted, the number of and type of awards to be granted, the provisions applicable to each grant and the time periods during which the awards may be exercised. No awards may be granted more than ten years after the date of the adoption of the plans.
Non-qualified stock options will be granted by the committee with an option price equal to the fair market value of the shares of common stock to which the non-qualified stock option relates on the date of grant. The governance, compensation and nominating committee may, in its discretion, determine to price the non-qualified option at a different price. In no event may the option price with respect to an incentive stock option granted under the plans be less than the fair market value of such common stock to which the incentive stock option relates on the date the incentive stock option is granted. However the price of an incentive stock option will not be less than 110% of the fair market value per share on the date of the grant in the case of an individual then owning more than 10% of the total combined voting power of all of our classes of stock of the corporation.
Each option granted under the plans will be exercisable for a term of not more than ten years after the date of grant. Certain other restrictions will apply in connection with the plans when some awards may be exercised.
Restricted stock will have full dividend, voting and other ownership rights, unless otherwise indicated in the applicable award agreement pursuant to which it is granted. If any dividends or distributions are paid in shares of common stock during the restricted period, the applicable award agreement may provide that such shares will be subject to the same restrictions as the restricted stock with respect to which they were paid.
As amended, the 2002-2003 plan terminates on October 13, 2018, and no options will be granted under these plans after that date.
These plans are intended to encourage directors, officers, employees and consultants to acquire ownership of common stock. The opportunity so provided is intended to foster in participants a strong incentive to put forth maximum effort for our continued success and growth, to aid in retaining individuals who put forth such effort, and to assist in attracting the best available individuals in the future.
On December 31, 2010, we granted to the Nevada General Corporation Law, our articles of incorporation exclude personal liability for our directors for monetary damages based upon any violation of their fiduciary duties as directors, except as to liability for any breachRobert G. Watson, Jr., 900,000 options that vest ratably over a 48 month period and are exercisable at $0.40 per share. The term of the dutyoptions is 5 years. The fair market value of loyalty, acts or omissions notthe options on the date of grant as calculated using the Black-Scholes model was $307,751, using the following weighted average assumptions: exercise price of $0.40 per share; common stock price of $0.40 per share; volatility of 128%; term of five years; dividend yield of 0%; interest rate of 1.95%. The amount recognized as expense in good faith or which involve intentional misconduct or a knowing violationthe year ended December 31, 2011 was $76,938, and the amount of law, or any transaction from which a director receives an improper personal benefit. This exclusion of liability does not limit any right which a director may haveexpense to be indemnified and does not affect any director’s liability under federal or applicable state securities laws. Werecognized in future periods is $230,813.
On June 1, 2012, we granted options for the purchase of 45,000 shares that vest a portion of the shares immediately, then the remaining 30,000 shares vests in three equal parts every six months over a three year period to two employees. In addition, we have agreed to indemnifygrant to Mr. Wright, our chief financial officer, an option expiring on July 31, 2017, to purchase 750,000 shares of our common stock at a cash exercise price equal to the fair market value of those shares as of the date when the option grant is approved by our board of directors. The options will vest in six equal tranches of 125,000 options every six months over a three year period, and Mr. Wright must exercise the options within three months of employment termination or forfeit them. The fair value of the option on the date of the grant was calculated using the Black-Scholes model was $167,032 using the following weighted average assumptions: exercise price of $0.70 per share; common stock price of $0.56 per share; volatility of 116%; term of three years; dividend yield of 0%; interest rate of .47%. The amount recognized as expense in the year ended December 31, 2012 was $18,825 and the amount of expense is recognized in future period is $148,208.
The 2013 Stock Incentive Plan
Our board of directors against expenses, judgments, and amounts paidstockholders have approved and adopted the EnerJex Resources, Inc., 2013 Stock Incentive Plan, which we refer to herein as the "Plan."
Summary of the Plan
The following is a summary of certain principal features of the Plan.
Administration of Plan; Board Authority to Select Grantees and Determine Awards. The Plan shall be administered by our board of directors. The Board shall have the power and authority to grant awards consistent with the terms of the Plan. The board may delegate this authority to a compensation committee of the board.
Stock Issuable Under the Plan; Mergers; Substitutions. The number of shares of stock initially reserved and available for issuance under the Plan shall be 5,000,000 shares, subject to adjustment as provided in Section 3.1(b) of the Plan. Pursuant to Section 3.1(b), we will increase the number of shares reserved and set aside annually on each January 1st by the lowest of the following: (i) five percent (5.0%) of the number of shares of stock issued and outstanding on the immediately preceding December 31st , (ii) five hundred thousand (500,000) shares, or (iii) such lesser number of shares as is determined by the board. For purposes of this limitation, the shares of stock underlying any awards that are forfeited, canceled, held back upon exercise of an option or settlement of an award to cover the exercise price or tax withholding, reacquired by us prior to vesting, satisfied without the issuance of stock or otherwise terminated (other than by exercise) shall be added back to the shares of stock available for issuance under the Plan. Subject to such overall limitations, shares of stock may be issued up to such maximum number pursuant to any type or types of award. The shares available for issuance under the Plan may be authorized but unissued shares of stock or shares of stock reacquired by us.
Eligibility. Grantees under the Plan will be such officers, directors, full or part-time employees, and other key persons (including consultants and prospective employees) of us and our subsidiaries, if any, as are selected from time to time by the board in its sole discretion. Currently, the number of officers is 2; the number of directors, 5; and the number of other employees and key personnel is [·].
Stock Options. Any stock option granted under the Plan shall be in such form as the board may from time to time approve. Stock options granted under the Plan may be non-qualified stock options or incentive stock options. Incentive stock options may be granted only to employees of us or any subsidiary that is a "subsidiary corporation" within the meaning of Section 424(f) of the Code.
Exercise Price. The exercise price per share for the stock covered by a stock option shall be determined by the board at the time of grant but shall not be less than 100% of the fair market value on the date of grant. In the case of an incentive stock option that is granted to a 10% owner, the option price of such Incentive stock option shall be not less than 110% of the fair market value on the grant date.
Option Term. The term of each stock option shall be fixed by the board, but no stock option shall be exercisable more than 10 years after the date the stock option is granted. In the case of an incentive stock option that is granted to a 10% owner, the term of such stock option shall be no more than 5 years from the date of grant.
Unrestricted and Restricted Stock Awards. The board may, in its sole discretion, grant (or sell at par value or such higher purchase price determined by the board) an unrestricted stock Award or restricted stock award under the Plan. Unrestricted stock awards and restricted stock awards may be granted in respect of past services or other valid consideration, or in lieu of cash compensation due to such grantee.
Amendments and Termination. The board may, at any time, amend or discontinue the Plan. We must obtain stockholder approval of any Plan amendment to the extent necessary and desirable to comply with Section 422 of the Internal Revenue Code or other applicable law, including the requirements of any exchange or quotation system on which our common stock is listed or quoted . Such plan amendments are subject to approval by our stockholders entitled to vote at a meeting of stockholders. We may not amend, alter, suspend, or terminate the Plan if doing so would impair the rights of any holder, unless both the holder and the Plan's administrator agree in writing and sign the writing.
Federal Income Tax Consequences. The following discussion is intended only as a brief summary of the federal income tax rules relevant to stock options and restricted shares. These rules are highly technical and subject to change. The following discussion is limited to the federal income tax rules relevant to us and to the individuals who are citizens or residents of the United States. The discussion does not address the state, local, or foreign income tax rules relevant to stock options or restricted cash payments.
Incentive Stock Options
A participant who is granted an incentive stock option generally recognizes no income upon grant or exercise of the option. The optionee, however, must include in his or her alternative minimum taxable income the excess of the fair market value of EnerJex shares on the date of exercise over the option exercise price. The IRS may take the position that the optionee must pay an alternative minimum tax notwithstanding the fact that the optionee receives no cash upon exercise of the incentive stock option for which the optionee can use to pay such tax.
If an optionee holds the common stock acquired upon exercise of the incentive stock option for at least two years from the date of grant and at least one year following exercise (Statutory Holding Periods), the IRS taxes the optionee’s gain, if any, upon a subsequent disposition of such common stock, as capital gain. But if an optionee disposes of common stock acquired by exercising an incentive stock option without satisfying the Statutory Holding Periods (Disqualifying Disposition), the optionee may recognize both compensation income and capital gain in the year of disposition. The compensation income amount generally equals the excess of (1) the lesser of the amount realized on disposition or the fair market value of the common stock on the exercise date over (2) the exercise price. This income is subject to income tax withholding, although it is not subject to employment tax withholding. Whether the balance of the gain that the optionee realizes on such a disposition, if any, will be taxed at long-term or short-term capital gain rates depends on whether the common stock has been held for more than one year following exercise of the incentive stock option.
Provided that the optionee satisfies the Statutory Holding Periods, we are not entitled to any deduction in connection with the grant or exercise of an incentive stock option or the optionee’s subsequent disposition of the shares that he or she acquired. If these holding periods are not satisfied, however, we are generally entitled to take a deduction in the year the optionee disposes of the common stock. The amount that we may deduct is equal to the optionee’s compensation income.
Non-Qualified Stock Options
A participant who is granted a non-qualified stock option recognizes no income when we grant the option. At the time that he or she exercises the option, however, the optionee recognizes compensation income. This compensation income equals the difference between the exercise price and the fair market value of our shares received on the date of exercise. This income is subject to both income and employment tax withholding. We are allowed to take an income tax deduction equivalent to the compensation income that the optionee recognizes.
Restricted Shares
Restricted shares are subject to a "substantial risk of forfeiture," as the term is used in Section 83 of the Internal Revenue Code. A participant to whom we grant restricted shares may make an election under Section 83(b) of the Code (a "Section 83(b) Election"). The consequence of the Section 83(b) Election is that the grant is taxed as compensation income at the date of receipt. Making such a Section 83(b) Election will cause the IRS to tax any claim againstfuture appreciation (or depreciation) in the value of the shares of common stock that we grant as capital gain (or loss) when the participant who has made a directorSection 83(b) Election subsequently sells the shares. Such an election must be made within 30 days of the date on which we issue the restricted shares. However, if he acted in good faitha participant opts not to make a Section 83(b) Election, then the grant shall be taxed as compensation income at the full fair market value on the date when the restrictions imposed on the shares expire. If the participant does not make a Section 83(b) Election, any dividends that we pay on common stock subject to the restrictions constitutes compensation income to the participant and incompensation expense to us. Any compensation income the participant recognizes from a manner he believedgrant of restricted shares is subject to be in our best interests.
Payment of Withholding Taxes
Under Section 11.2 of the Plan, we have the right to withhold or require a participant to remit to us an amount sufficient to satisfy any federal, state, local, or foreign withholding tax requirements on any grant or exercise made under the Plan.
Employment Agreements
Robert G. Watson, Jr. – Chief Executive Officer
On December 31, 2012, we entered into an amended and restated employment agreement with Robert G. Watson, Jr., pursuant to which (i) we will employ Mr. Watson as its chief executive officer for a term ending on December 31, 2014, (ii) we will pay to Mr. Watson base compensation of $225,000 per year, plus such discretionary cash bonus as the board of directors determines to be appropriate, and (iii) if we terminate Mr. Watson's employment without "Cause" (as defined in the amended and restated employment Agreement), then we will pay to Mr. Watson as severance pay (A) the base compensation that would have accrued during the remainder of the term of that amended and restated employment agreement, and (B) if that termination occurs after 16 months of employment, we also will pay to Mr. Watson additional severance pay in the amount of $150,000.
Douglas M. Wright – Chief Financial Officer
On August 1, 2008,15, 2012, we entered into an employment agreement with C. Stephen Cochennet,Douglas M. Wright, pursuant to which (i) we will employ Mr. Wright as chief financial officer for a term ending on December 31, 2013; (ii) we will pay to Mr. Wright base compensation of $140,000 plus such discretionary bonus as our presidentboard of directors determines to be appropriate; (iii) we have agreed to seek approval of a new stock incentive plan and chief executive officer.the reservation thereunder of shares sufficient in order to enable us to grant to Mr. Cochennet’sWright an option to purchase 750,000 shares of common stock, expiring on July 31, 2017, vesting in six equal tranches of 125,000 options every six months over a period of 3 years, and exercisable at a price per share equal to the fair market value of our common stock on the date on which the option grant to Mr. Wright is formally approved by our board of directors; and (iv) if we terminate Mr. Wright's employment agreement was approvedwithout "Cause" (as defined in the employment agreement), then we will pay to Mr. Wright as severance pay in the amount of $35,000.
| 45 |
Termination Under the Equity Plans
Under our 2000/2001 Stock Option Plan, if the person receiving the option (the optionee) ceases to be employed by us for any reason other than for disability or cause, the optionee's options will expire not later than 3 months afterwards. During this 3 month period and prior to the time the option expires under the terms of the option, the optionee may exercise any option that we have granted to him, but only to the extent that the options were exercisable on the date of termination of his employment. Unless exercised during this period, these options will expire at the end of the 3 month period unless the options are to terminate sooner under the terms and conditions of the option. The decision as to whether a termination for a reason other than disability, cause or death has occurred are made by the board of directors, whose decision shall be final and conclusive. If an optionee ceases to be employed by us for reason of disability, the optionee's options will expire not later than 1 year after the date that he or she is terminated. During this 1 year period and prior to the expiration of the option under its terms, the optionee may exercise any option granted to him, but only to the extent that the options were exercisable on the date of termination of his employment because of his or her disability. Except as so exercised, optionee's options will expire at the end of the one 1 year period unless the options are to terminate sooner under the terms and conditions of the option. The decision as to whether a termination by reason of disability has occurred is determined by the board.
Under our Amended and Restated 2002-2003 Stock Option Plan, if an optionee ceases to be employed by, or ceases to have a relationship with us for any reason other than for disability or cause, the optionee's options will expire not later than three 3 months thereafter. During the three month period and prior to the expiration of the option by its terms, the optionee may exercise any option granted to him, but only to the extent such options were exercisable on the date of termination of his employment or relationship and except as so exercised, such options shall expire at the end of such three month period unless such options by their terms expire before such date. The decision as to whether a termination for a reason other than disability, cause or death has occurred are made by the governance, compensation and nominating committee, whose decision shall be final and conclusive, except that employment shall not be considered terminated in the case of our boardsick leave or other bona fide leave of directors.
Termination Under the Employment Agreements
Termination Without Cause or Disability, Including a Change in Control
Under Mr. Cochennet’sWatson's employment agreement, contains provisions concerning termsif Mr. Watson is terminated not for cause or disability, we will pay Mr. Watson all accrued and unpaid wages, including for accrued and unused vacation time and any annual bonus accrued through the date of employment, voluntary and involuntary termination, indemnification, severance payments, and other termination benefits, intermination. In addition, to a non-compete clause and certain other perquisites, such as long-term disability insurance, director and officer insurance, andhe will receive the salary that he would have earned through December 31, 2014. If Mr. Watson is terminated after June 31, 2014, he will also receive an automobile allowance. The original termadditional sum of $150,000.
Under Mr. Cochennet’sWright's employment agreement, runs from August 1, 2008 untilif Mr. Wright is terminated not for cause or disability, we will pay Mr. Wright all accrued and unpaid wages, including for accrued and unused vacation time and any annual bonus accrued through the date of termination. If Mr. Wright is terminated after February 15, 2014, he will also receive an additional sum of $35,000.
Termination Because of Disability
Under Mr. Watson's and Mr. Wright's employment agreements, if the employee is terminated because of disability, he is entitled to receive all accrued and unpaid wages, including for accrued and unused vacation time and any annual bonus accrued through the date of termination.
Option Exercises for Fiscal 2013
There were no options exercised by our Named Executive Officers in fiscal year 2013.
Grants of Plan-Based Awards in Fiscal Year 2013
We have agreed to grant to Mr. Wright an option expiring on July 31, 2011. The term of the employment agreement is automatically extended for additional one year terms unless otherwise terminated in accordance with its terms.
| Potential | Maximum # | Option | |||||||||||
Fiscal Year | Grant Date | of Options | Strike Price of Options | Expiration Date* | |||||||||
| 2009 | 7/01/2009 | 30,000 | Fair market value on grant date | 6/30/2012 | |||||||||
| 2010 | 7/01/2010 | 45,000 | Fair market value on grant date | 6/30/2013 | |||||||||
| 2011 | 7/01/2011 | 60,000 | Fair market value on grant date | 6/30/2014 | |||||||||
Outstanding Equity Awards at 2013 Fiscal Year-End
The following table lists the requestoutstanding equity incentive awards held by our named executive officers as of the board’s compensation committee and with the approval offiscal year ended December 31, 2013.
| Name | Option Awards | Stock Awards | ||||||||||||||||||||||||||||
| Fiscal Year | Number of securities underlying unexercised options exercisable (#) | Number of securities underlying unexercised options unexercisable (#) | Number of securities underlying unexercised unearned options (#) | Option exercise price ($) | Option expiration date | Number of shares or units of stock that have not vested | Market value of shares or units of stock that have not vested | |||||||||||||||||||||||
| Robert G. Watson, Jr. | 2010 | - | - | 900,000 | (1) | $ | 0.40 | 12/31/2015 | - | - | ||||||||||||||||||||
| Douglas M. Wright | 2012 | - | - | 750,000 | (2) | $ | 0.70 | 7/31/2017 | - | - | ||||||||||||||||||||
(1) Stock options issued to Mr. Cochennet in an effortWatson pursuant to reduce compensation expense which, through non-cash, would have had a substantial negative impact on our financial statements and results of operations for the quarter ended September 30, 2008. Shares2008 Stock Incentive Plan are subject to thesetime-based vesting requirements, which must be satisfied before the options were returnedare fully vested and eligible to the planbe exercised. The options vest in equal monthly increments over a period of 48 months, and are available for future issuance. On August 3, 2009, we issued Mr. Cochennet 18,800 sharesin full upon a change of twelve month restricted stock in consideration for the prior rescissioncontrol of the company or the sale of all or substantially all of its assets. The options discussed above.
(2) We have agreed to stock options and restricted shares).
Director Compensation
The following table presentssets forth summary compensation information for the period ended December 31, 2013, for each of our non-employee directors.
| Name | Fees Earned or Paid in Cash $ | Stock Awards $ | Option Awards (1) $ | All Other Compensation $ | Total $ | |||||||||||||||
| James G. Miller (2) | $ | $ | $ | -0- | $ | $ | ||||||||||||||
| (1) | Amount represents the estimated fair market value of shares of common stock issued for board retainer fees for the year-end period ended December 31, 2013 under SFAS 123(R). |
| (2) | For 2013, Mr. Miller received a grant of shares of common stock at a fair market value of $.70 per share, as compensation for his services to the company. |
Aggregated Option/SAR* Exercises In Last Fiscal Year
and FY End Option/SAR Values
| Name | Shares Acquired on Exercise | Value Realized | Number of Exercisable Securities Underlying Unexercised Options at FY-End | Value of Unexercised In-the-money Options At FY-End Exercisable | ||||||||||||
| James G. Miller | $ | |||||||||||||||
*We have not granted any Stock Appreciation Rights ("SAR").
For 2012, James G. Miller, the Company's independent director and chairman of its audit and governance, compensation and nominating committees, was compensated for his services by a grant of 50,000 shares of the Company's common stock.
Key 2013 and Recent Compensation-Related Actions
During 2013, EnerJex took a number of actions that supported EnerJex's executive compensation philosophy and objective of ensuring that EnerJex's executive compensation program reinforces pay for performance, is market competitive in order to attract and retain key employees and is aligned with the interests of EnerJex stockholders.
| · | At EnerJex's 2013 annual meeting of stockholders, EnerJex stockholders had the opportunity to provide an advisory vote on the compensation paid to EnerJex's named executive officers, or a "say-on-pay" vote. Approximately [·] percent of the votes cast by EnerJex stockholders were in favor of the "say-on-pay" vote. While the governance, compensation and nominating committee believes that such results generally affirmed stockholder support of EnerJex's approach to executive compensation and did not make any significant changes to EnerJex's executive compensation program solely in response to the vote, the governance, compensation and nominating committee, nonetheless, has kept and intends to continue to keep a watchful eye on EnerJex's executive compensation program in order to ensure that it reinforces pay for performance, is market competitive in order to attract and retain key employees and is aligned with the interests of EnerJex stockholders. |
| · | At EnerJex's 2013 annual meeting of stockholders, EnerJex stockholders had the opportunity to provide an advisory vote on the frequency with which they believed EnerJex should hold a say-on-pay vote. In response to the voting results for the frequency of the say-on-pay vote, in which the frequency of a say-on-pay vote every three years received the highest number of votes, EnerJex intends to provide EnerJex stockholders with the opportunity to provide a say-on-pay advisory vote every three years until the next required vote on the frequency of a say-on-pay vote. |
SECURITY OWNERSHIP OF MANAGEMENT AND PRINCIPAL STOCKHOLDERS
The following table sets forth information as of February [·], 2014 with respect to the best of EnerJex’s knowledge, about thebeneficial ownership of EnerJex’s common stock on November 16, 2009 relating to those persons known to beneficially own more than 5% of EnerJex’sour capital stock and by EnerJex’s directors and executive officers. The percentagestock:
| · | each person known by EnerJex that beneficially own more than five percent of any class of voting securities; |
| · | each director of the Company; |
| · | each named executive officer of the Company; and |
| · | all directors and named executive officers as a group. |
Percentage of beneficial ownership for the following tableis calculated based on [·] shares of EnerJex common stock outstanding and 4,779,460 shares of EnerJex Series A preferred stock outstanding as of February [·], 2014. The percent of common stock and Series A preferred stock of EnerJex is based on 4,800,660[·] shares of common stock outstanding.
The number of shares beneficially owned by a person includes shares of common stocksubject to options and warrants held by that the stockholder has a right to acquireperson that are currently exercisable or that become exercisable within 60 days after November 16, 2009of February [·], 2014. Percentage calculations assume, for each person and group, that all shares that may be acquired by such person or group pursuant to options and warrants conversion privilegescurrently exercisable or other right. Thethat become exercisable within 60 days of February [·], 2014 are outstanding for the purpose of computing the percentage ownershipof capital stock of the Company owned by such person or group. However, such unissued shares of capital stock are not deemed to be outstanding commonfor calculating the percentage of capital stock however, is based onowned by any other person. EnerJex and Black Raven believe that the assumption, expressly requiredbeneficial owners of capital stock listed in the table below have sole voting and investment power with respect to all shares shown as beneficially owned by them, subject to community property laws where applicable. Unless otherwise indicated in the rulesnotes below, the address for each of the Securities and Exchange Commission, that onlystockholders in the person or entity whose ownershiptable below is being reported has converted options or warrants into shares of EnerJex’s common stock.
Name and Address of Beneficial Owner, Officer or Director(1) | Number of Shares | Percent of Outstanding Shares of Common Stock(2) | ||||||
C. Stephen Cochennet, President & Chief Executive Officer(3) | 468,800 | (4) | 9.8 | % | ||||
Dierdre P. Jones, Chief Financial Officer(3) | 15,000 | (5) | * | |||||
Robert (Bob) G. Wonish, Director(3) | 22,000 | * | ||||||
Darrel G. Palmer, Director(3) | 22,000 | * | ||||||
Daran G. Dammeyer, Director(3) | 38,102 | * | ||||||
Dr. James W. Rector, Director(3) | 14,500 | * | ||||||
| Directors and Officers as a Group | 580,402 | 12.1 | % | |||||
West Coast Opportunity Fund LLC(6) West Coast Asset Management, Inc. Paul Orfalea, Lance Helfert & R. Atticus Lowe 2151 Alessandro Drive, #100 Ventura, CA 93001 | 1,504,098 | 31.3 | % | |||||
Enable Growth Partners L.P.(7) Enable Capital Management, LLC Mitchell S. Levine One Ferry Building, Suite 225 San Francisco, CA 94111 | 640,560 | 13.3 | % | |||||
| Name of Beneficial Owner(1) | EnerJex Common Stock and Common Stock Equivalents | Percent of Class(2) | ||||||
| Robert G. Watson, Jr., CEO/President, Director(3) | 4,000,000 | 3.7 | % | |||||
| Douglas M. Wright, Chief Financial Officer | 150,000 | 0.1 | % | |||||
| R. Atticus Lowe, Director(4)(6) | 128,000 | 0.1 | % | |||||
| Lance W. Helfert, Director(4)(7) | 201,999 | 0.2 | % | |||||
| James G. Miller, Director | 2,174,000 | 2.0 | % | |||||
| Montecito Venture Partners, LLC(5) | 176,312 | 31 | % | |||||
| West Coast Opportunity Fund, LLC | ||||||||
| 120 S Coast Village Road Montecito, CA 93108 | 52,817,871 | 48.3 | % | |||||
| Orfalea Family Revocable | 9,013,459 | 8.2 | % | |||||
| Newman Family Trust | 5,500,000 | 5.0 | % | |||||
| All current EnerJex directors and executive officers as a group (eight persons) | 78,161,641 | 71.5 | % | |||||
* Indicates less than one percent.
| (1) | As used in this table, The address of each person is care of the Registrant, 4040 Broadway, Suite 508, San Antonio, Texas 78209. |
| (2) | Figures are rounded to the nearest tenth of a percent. |
| (3) |
| (4) |
| (5) |
| (6) |
| (7) |
| 48 |
CERTAIN RELATIONSHIPS AND RELATED PARTY TRANSACTIONS
The EnerJex board of directors has delegated to the audit committee, pursuant to the terms of a written policy, the authority to review, approve and ratify related party transactions. If it is not feasible for the audit committee to take an action with respect to a proposed related party transaction, the EnerJex board of directors or another committee of the EnerJex board of directors, may approve or ratify it. No member of the EnerJex board of directors or any committee may participate in any review, consideration or approval of any related party transaction with respect to which such member or any of his or her immediate family members is the related party.
EnerJex's policy defines a "related party transaction" as a transaction, arrangement or relationship (or any series of similar transactions, arrangements or relationships) in which EnerJex (including any of its subsidiaries) were, are or will be a participant and in which any related party had, has or will have a direct or indirect interest.
Prior to entering into or amending any related party transaction, the party involved must provide notice to EnerJex of the facts and circumstances of the proposed transaction, including:
| · | the related party's relationship to EnerJex and his or her interest in the transaction; |
| · | the material facts of the proposed related party transaction, including the proposed aggregate value of such transaction or, in the case of indebtedness, the amount of principal that would be involved; |
| · | the purpose and benefits of the proposed related party transaction with respect to EnerJex; |
| · | if applicable, the availability of other sources of comparable products or services; and |
| · | an assessment of whether the proposed related party transaction is on terms that are comparable to the terms available to an unrelated third party or to employees generally. |
If EnerJex determines the proposed transaction is a related party transaction and the amount involved will or may be expected to exceed $10,000 in any calendar year, the proposed transaction is submitted to the audit and finance committee for its prior review and approval or ratification. In determining whether to approve or ratify a proposed related party transaction, the audit committee will consider, among other things, the following:
| · | the purpose of the transaction; |
| · | the benefits of the transaction to EnerJex; |
| · | the impact on a |
| · | the availability of other sources for comparable products or services; |
| · | the terms of the transaction; and |
| · | the terms available to |
Related party transactions that involve $10,000 or less must be disclosed to the audit committee but are not required to be approved or ratified by the audit committee.
EnerJex also produces quarterly reports to the audit committee of any amounts paid or payable to, or received or receivable from, any related party. These reports allow EnerJex to identify any related party transactions that were not previously approved or ratified. In that event, the transaction will be promptly submitted to the audit committee for consideration of all the relevant facts and circumstances, including those considered when a transaction is submitted for pre-approval. Under EnerJex's policy, certain related party transactions as defined under the policy, such as certain transactions not requiring disclosure under the rules of the SEC, will be deemed to be pre-approved by the audit committee and will not be subject to these procedures.
There were no related party transactions for EnerJex during 2013.
| 49 |
DESCRIPTION OF CAPITAL STOCK
Authorized and Outstanding Capital Stock
EnerJex currently is authorized to issue 250,000,000 shares of common stock, $0.001 par value per share, 4,779,460 shares of which 4,800,660EnerJex Series A preferred stock, $0.001 par value per share, and 25,000,000 million shares wereof undesignated preferred stock, $0.001 par value per share.
As of February [·], 2014, EnerJex had [·] shares of EnerJex common stock outstanding. As of [·], 2014, EnerJex had an aggregate of 5 million shares of EnerJex common stock reserved for issuance upon the exercise of outstanding asstock options granted under the EnerJex Resources, Inc. 2013 Stock Incentive Plan. As of November 16, 2009.[·], 2014, EnerJex had an aggregate of 550,000 shares of EnerJex common stock reserved for issuance upon the exercise of outstanding warrants.
As of [·], 2014, EnerJex had 4,779,460 shares of EnerJex Series A preferred stock outstanding. Each share of EnerJex Series A preferred stock entitles its holder to one vote per share. Each share of EnerJex Series A preferred stock is convertible, at the option of the holder, for one share of EnerJex common stock, at an exchange price of $1.00 per share, subject to adjustment upon certain capitalization events. Holders of commonEnerJex Series A preferred stock are entitled to receive dividends. Holders of EnerJex Series A preferred stock are entitled to participate in the distribution of EnerJex's assets upon any liquidation, dissolution or winding-up of EnerJex. The holders of EnerJex Series A preferred stock have no cumulative voting, preemptive, subscription, redemption or sinking fund rights.
Common Stock
For all matters submitted to a vote of EnerJex stockholders, each holder of EnerJex common stock is entitled to one vote for each share registered in the holder's name on EnerJex's books. EnerJex common stock does not have cumulative voting rights. HoldersThe holders of a majority of the shares of EnerJex common stock and Series A preferred stock entitled to vote in any election of directors, voting together as a single class, can elect all of the directors standing for election, if they so choose. Subject to limitations under Nevada law and preferences that may be applicable to any then outstanding preferred stock, holders of EnerJex common stock are entitled to sharereceive ratably inthose dividends, if any, as may be declared by the EnerJex board of directors out of legally available funds. Upon the liquidation, dissolution or winding up of EnerJex, the holders of EnerJex common stock will be entitled to share ratably in the net assets legally available for distribution to stockholders after the payment of all of EnerJex's debts and other liabilities, subject to the prior rights of any preferred stock then outstanding. All shares of outstanding EnerJex common stock are fully paid and nonassessable. Holders of EnerJex common stock do not have preemptive or subscription rights, and they have no right to convert their EnerJex common stock into any other securities. There are no redemption or sinking fund provisions applicable to the EnerJex common stock. The rights, preferences and privileges of the holders of EnerJex common stock are subject to the rights of the holders of any series of preferred stock which EnerJex may designate in the future. EnerJex's articles of incorporation and bylaws do not restrict the ability of a holder of EnerJex common stock to transfer the holder's shares of EnerJex common stock.
Series A Preferred Stock
Each share of EnerJex Series A preferred stock entitles its holder to one vote per share. Each share of EnerJex Series A preferred stock is exchangeable, at the option of the holder, for one share of EnerJex common stock, at an exchange price of $1.00 per share, subject to adjustment upon certain capitalization events. Holders of EnerJex Series A preferred stock are entitled to receive dividends. Holders of EnerJex Series A preferred stock are entitled to participate in the distribution of EnerJex's assets upon any liquidation, dissolution or winding-up of EnerJex. There are fifteen record holders of EnerJex Series A preferred stock and they have no cumulative voting, preemptive, subscription, redemption or sinking fund rights.
Preferred Stock
The EnerJex board of directors is authorized, without approval of EnerJex stockholders subject to any limitations prescribed by law, to issue up to an aggregate of 25 million shares of preferred stock in one or more series and to fix the rights, preferences, privileges and restrictions granted to or imposed upon the preferred stock, including voting rights, dividend rights, conversion rights, redemption privileges and liquidation preferences. The rights of the holders of EnerJex common stock and Series A preferred stock will be subject to, and may be adversely affected by, the rights of holders of any preferred stock that may be issued in the future. The EnerJex board of directors could authorize the issuance of shares of preferred stock with terms and conditions more favorable than the EnerJex common stock or Series A preferred stock and with rights that could adversely affect the voting power or other rights of holders of the EnerJex common stock or Series A preferred stock. Prior to issuance of shares of each series of undesignated preferred stock, the EnerJex board of directors is required by the Nevada Revised Statutes and EnerJex's amended and restated articles of incorporation to adopt resolutions and file a Certificate of Designations with the Secretary of State of the State of Nevada, fixing for each such series the designations, powers, preferences, rights, qualifications, limitations and restrictions of the shares of such series. Issuance of preferred stock, while providing flexibility in connection with possible acquisitions and other corporate purposes, could have the effect of delaying, deferring or preventing a change in control of EnerJex.
Anti-Takeover Effects of Provisions of EnerJex's Amended and Restated Articles of Incorporation and Bylaws and Nevada Law
Some provisions of EnerJex's amended and restated articles of incorporation and bylaws and Nevada law contain provisions that could make the following transactions more difficult: an acquisition of EnerJex by means of a tender offer; an acquisition of EnerJex by means of a proxy contest or otherwise; or removal of EnerJex's incumbent officers and directors. It is possible that these provisions could make it more difficult to accomplish or could deter transactions that EnerJex stockholders may otherwise consider to be in their best interest or in EnerJex's best interests, including transactions that might result in a premium over the market price for EnerJex's shares.
These provisions, summarized below, are designed to discourage coercive takeover practices and inadequate takeover bids. These provisions also are designed to encourage persons seeking to acquire control of EnerJex to first negotiate with the EnerJex board of directors. The EnerJex board of directors believes that the benefits of increased protection of its potential ability to negotiate with the proponent of an unfriendly or unsolicited proposal to acquire or restructure EnerJex outweigh the disadvantages of discouraging these proposals because negotiation of these proposals could result in an improvement of their terms.
Articles of Incorporation and Bylaws
The following provisions in EnerJex's amended and restated articles of incorporation and bylaws could delay or discourage transactions involving an actual or potential change in control or change in EnerJex's management, including transactions that EnerJex stockholders may otherwise consider to be in their best interest or in EnerJex's best interests, including transactions that might result in a premium over the market price for EnerJex's shares.
| · | Authorized But Unissued Capital Stock. EnerJex has shares of common stock and undesignated preferred stock available for future issuance without stockholder approval. EnerJex may use these additional shares for a variety of corporate purposes, including for future public offerings to raise additional capital or to facilitate corporate acquisitions or for payment as a dividend on its capital stock. The existence of unissued and unreserved capital stock may enable the EnerJex board of directors to issue shares to persons friendly to current management that could render more difficult or discourage a third-party attempt to obtain control of EnerJex by means of a merger, tender offer, proxy contest or otherwise, thereby protecting the continuity of EnerJex's management. In addition, the ability to authorize undesignated preferred stock makes it possible for the EnerJex board of directors to issue preferred stock with voting or other rights or preferences that could impede the success of any attempt to change control of EnerJex. These and other provisions may have the effect of deferring hostile takeovers or delaying changes in control or management of EnerJex. |
| · | Stockholder Meetings. EnerJex's bylaws provide that a special meeting of stockholders may be called only by EnerJex's chairman of the board, president and chief executive officer, or by the EnerJex board of directors. |
| · | Requirements for Advance Notification of Stockholder Nominations and Proposals. EnerJex's bylaws establish advance notice procedures with respect to stockholder proposals and the nomination of candidates for election as directors, other than nominations made by or at the direction of the EnerJex board of directors or a committee of the EnerJex board of directors. |
| · | No Cumulative Voting Rights. EnerJex's amended and restated articles of incorporation and bylaws do not provide for cumulative voting rights. The holders of a majority of the shares of common stock and Series A preferred stock entitled to vote in any election of directors, voting together as a single class, can elect all of the directors standing for election, if they so choose. |
Nevada Anti-Takeover Law
As a Nevada corporation, EnerJex is subject to Section 78.411 to 78.444 of the Nevada Revised Statutes. This law prohibits a publicly-held Nevada corporation from engaging in any business combination with any interested stockholder for a period of three years following the date that the stockholder became an interested stockholder unless:
| · | prior to the date of the transaction, the board of directors of the corporation approved either the business combination or the transaction which resulted in the stockholder becoming an interested stockholder; |
| · | upon consummation of the transaction which resulted in the stockholder becoming an interested stockholder, the interested stockholder owned at least 85 percent of the voting stock of the corporation outstanding at the time the transaction commenced, excluding for purposes of determining the number of shares outstanding those shares owned by persons who are directors and also officers and by employee stock plans in which employee participants do not have the right to determine confidentially whether shares held subject to the plan will be tendered in a tender or exchange offer; or |
| · | on or subsequent to the date of the transaction, the business combination is approved by the board of directors and authorized at an annual or special meeting of stockholders, and not by written consent, by the affirmative vote of at least two-thirds of the outstanding voting stock which is not owned by the interested stockholder. |
Section 78-416 of the Nevada Revised Statues defines "business combination" to include:
| · | any merger or consolidation involving the corporation and the interested stockholder; |
| · | any sale, transfer, pledge or other disposition of 10 percent or more of the corporation's assets involving the interested stockholder; |
| · | in general, any transaction that results in the issuance or transfer by the corporation of any of its stock to the interested stockholder; or |
| · | the receipt by the interested stockholder of the benefit of any loans, advances, guarantees, pledges or other financial benefits provided by or through the corporation. |
Limitation of Liability and Indemnification
EnerJex's amended and restated articles of incorporation contains certain provisions permitted under the Nevada Revised Statutes relating to the liability of directors. The provisions eliminate a director's liability for monetary damages for a breach of fiduciary duty, except in circumstances involving wrongful acts, such as the breach of a director's duty of loyalty or acts or omissions that involve intentional misconduct or a knowing violation of law.
In addition, EnerJex's amended and restated articles of incorporation contain provisions to indemnify EnerJex's directors and officers to the fullest extent permitted by the Nevada Revised Statutes.
Transfer Agent and Registrar
The transfer agent and registrar for EnerJex common stock is Standard Registrar & Transfer Co., Inc.
DESCRIPTION OF OUR SERIES B PREFERRED STOCK
The terms of the Series B Preferred Stock are contained in a certificate of designation that amends our articles of incorporation, as amended. The following description is a summary of the material provisions of the Series B Preferred Stock and the certificate of designation. It does not purport to be complete. We urge you to read the certificate of designation because it, and not this description, defines your rights as a holder of shares of Series B Preferred Stock. As used in this section, the terms “EnerJex,” “us,” “we” or “our” refer to EnerJex Resources, Inc. and not any of its subsidiaries.
General
Our board of directors is authorized to cause us to issue, from our authorized but unissued shares of preferred stock, one or more series of preferred stock, to establish from time to time by the number of shares to be included in each such series, and to fix the designation and any preferences, conversion and other rights, voting powers, restrictions, limitations as to dividends, qualifications and terms and conditions of redemption of the shares of each such series. Pursuant to this authority, prior to this offering, our board of directors established the terms of the Series B Preferred Stock, which are described below.
When issued, the Series B Preferred Stock will be validly issued, fully paid and non-assessable. The holders of the Series B Preferred Stock have no preemptive rights with respect to any of our stock or any securities convertible into or carrying rights or options to purchase any such stock. The Series B Preferred Stock is not subject to any sinking fund or other obligation of us to redeem or retire the Series B Preferred Stock, but we may redeem the Series B Preferred Stock as described below under “Redemption.” Unless redeemed or repurchased by us, the Series B Preferred Stock will have a perpetual term with no maturity.
The Series B Preferred Stock will be issued and maintained in its discretion, frombook-entry form registered in the name of the nominee, The Depository Trust Company, except in limited circumstances. See “Book-Entry Procedures” below.
The transfer agent, registrar and dividend disbursing agent for the Series B Preferred Stock is Standard Registrar & Transfer, Inc.
Ranking
The Series B Preferred Stock ranks:
| · | senior to our common stock and any other equity securities that we may issue in the future, the terms of which specifically provide that such equity securities rank junior to such Series B Preferred Stock, in each case with respect to payment of dividends and amounts upon liquidation, dissolution or winding up, referred to as “junior shares;” |
| · | equal to any shares of equity securities that we may issue in the future, the terms of which specifically provide that such equity securities rank on par with such Series B Preferred Stock, in each case with respect to payment of dividends and amounts upon liquidation, dissolution or winding up, referred to as “parity shares;” |
| · | pari passu with our Series A Preferred Stock; |
| · | junior to all other equity securities issued by us, the terms of which specifically provide that such equity securities rank senior to such Series B Preferred Stock, in each case with respect to payment of dividends and amounts upon liquidation, dissolution or winding up (any such creation would require the affirmative vote of the holders of at least a majority of the outstanding shares of Series B Preferred Stock), referred to, as “senior shares;” and |
| · | junior to all our existing and future indebtedness. |
Dividends
Holders of the Series B Preferred Stock are entitled to receive, when and as declared by our board of directors, out of funds legally available for the payment of dividends, cumulative cash dividends at the rate of [·]% per annum of the $25.00 per share liquidation preference, equivalent to $[·] per annum per share.
With respect to quarterly dividend periods, the dividend payment date shall be each January 31, April 30, July 31, and October 31, commencing [·], 2014. The record date for each quarterly dividend period shall be the business day immediately prior to each dividend payment date, and the dividends for each quarterly dividend period to be distributed.paid at the end of such month to such holders of record. Holders of Series B Preferred Stock will only be entitled to dividend payments for each monthly dividend period pursuant to which they are the holder of record as of the applicable record date. Dividends will generally be payable quarterly in arrears on the dividend payment date; provided, that if such day falls on a national holiday or a weekend, such dividends will be due and payable on the next business day following such weekend or national holiday. Dividends payable on the shares of Series B Preferred Stock for any partial dividend period will be computed on the basis of a 360-day year consisting of twelve 30-day months. We will pay dividends to holders of record as they appear in our stock records at the close of business on the applicable record date.
We will not declare or pay or set aside for payment any dividend on the shares of Series B Preferred Stock if the terms of any of our agreements or senior shares, including agreements relating to our indebtedness and the certificate of designation relating to our Series A Preferred Stock, prohibit that declaration, payment or setting aside of funds or provide that the declaration, payment or setting aside of funds is a breach of or a default under that agreement, or if the declaration, payment or setting aside of funds is restricted or prohibited by law. The terms of our Series A Preferred Stock prohibit the payment of cash dividends on our equity securities ranking junior to the Series A Preferred Stock, which will include the Series B Preferred Stock, unless all accrued dividends on the Series A Preferred Stock have been paid in full in cash or in kind, but the terms of our Series B Preferred Stock do not require us to declare a dividend on such shares. In addition, future debt, contractual covenants or arrangements we enter into may restrict or prevent future dividend payments. See the eventrisk factor entitled “We could be prevented from paying dividends on the Series B Preferred Stock” on page [·] of this prospectus for additional information.
Notwithstanding the foregoing, however, dividends on the shares of Series B Preferred Stock will accrue regardless of whether: (i) the terms of our senior shares or our agreements, including our existing or future indebtedness, at any time prohibit the current payment of dividends; (ii) we have earnings; (iii) there are funds legally available for the payment of such dividends; or (iv) such dividends are declared by our board of directors. Except as otherwise provided, accrued but unpaid distributions on the shares of Series B Preferred Stock will not bear interest, and holders of the shares of Series B Preferred Stock will not be entitled to any distributions in excess of full cumulative distributions as described above. All of our dividends on the shares of Series B Preferred Stock will be credited to the previously accrued dividends on the shares of Series B Preferred Stock. We will credit any dividends paid on the shares of Series B Preferred Stock first to the earliest accrued and unpaid dividend due. As described more fully above, the payment of dividends with respect to the Series B Preferred Stock is subordinate to any dividends to which holders of our Series A Preferred Stock are entitled.
We may not declare or pay any dividends, or set aside any funds for the payment of dividends, on shares of common stock or other junior shares, or redeem, purchase or otherwise acquire shares of common stock or other junior shares, unless we also have declared and either paid or set aside for payment the full cumulative dividends on the shares of Series B Preferred Stock for all past dividend periods.
If we do not declare and either pay or set aside for payment the full cumulative dividends on the shares of Series B Preferred Stock and all parity shares, the amount which we have declared will be allocated pro rata to the shares of Series B Preferred Stock and to each parity share so that the amount declared for each share of Series B Preferred Stock and for each parity share is proportionate to the accrued and unpaid distributions on those shares.
Failure to Make Dividend Payments
If we have committed a dividend default by failing to pay the accrued cash dividends on the outstanding Series B Preferred Stock in full for any six consecutive or non-consecutive quarterly periods, then until we have paid all accrued dividends on the shares of our Series B Preferred Stock for all dividend periods up to and including the dividend payment date on which the accumulated and unpaid dividends are paid in full the annual dividend rate on the Series B Preferred Stock will be increased by 2% to 12% per annum, which we refer to as the Penalty Rate, commencing on the first day after the dividend payment date on which such dividend default occurs. Thereafter, the Penalty Rate shall be increased by 2% each successive time we fail to pay the accrued cash dividends on the outstanding Series B Preferred Stock, up to a maximum of 19%.
If we have committed a dividend default by failing to pay the accrued cash dividends on the outstanding Series B Preferred Stock in full for any six consecutive or non-consecutive quarterly periods, then until we have paid all accrued dividends on the shares of our Series B Preferred Stock for all dividend periods up to and including the dividend payment date on which the accumulated and unpaid dividends are paid in full the holders of our Series B Preferred Stock will have the voting rights described below, until we have paid all dividends on the shares of our Series B Preferred Stock for all dividend periods up to and including the dividend payment date on which the accumulated and unpaid dividends are paid in full.
Once we have paid all accumulated and unpaid dividends in full and have paid cash dividends at the Penalty Rate in full for each quarter for an additional two consecutive quarters, the dividend rate will be restored to the stated rate and the foregoing provisions will not be applicable, unless we again fail to pay any quarterly dividend for any future quarter.
Failure to Maintain National Market Listing of Series B Preferred Stock
If we list the Series B Preferred Stock on a national exchange and then fail to continuously maintain that listing, then: (i) the annual dividend rate on the Series B Preferred Stock will be increased to the Penalty Rate commencing on the 31 st consecutive day that the Series B Preferred Stock is not listed on a national exchange, and (ii) holders of Series B Preferred Stock will have the voting rights described below. See “Voting Rights” below. When the Series B Preferred Stock is once again listed on a national exchange, the dividend rate will be restored to the Stated Rate and the foregoing provisions will not be applicable, unless the Series B Preferred Stock is again no longer listed on a national exchange.
Liquidation Preference
Upon any voluntary or involuntary liquidation, dissolution or winding up of our affairs, then, before any distribution or payment shall be made to the holders of any common stock or any other class or series of junior shares in the distribution of assets upon any liquidation, dissolution or winding up of us, the holders of sharesSeries B Preferred Stock shall be entitled to receive out of common stockour assets legally available for distribution to stockholders, liquidating distributions in the amount of the liquidation preference, or $25.00 per share, plus an amount equal to all dividends (whether or not earned or declared) accrued and unpaid thereon. After payment of the full amount of the liquidating distributions to which they are entitled, the holders of Series B Preferred Stock will have no right or claim to share pro rataany of our remaining assets. In the event that, upon any such voluntary or involuntary liquidation, dissolution or winding up, our available assets are insufficient to pay the amount of the liquidating distributions on all assets remainingoutstanding Series B Preferred Stock and the corresponding amounts payable on all senior shares and parity shares, then after payment of the liquidating distribution on all outstanding senior shares, the holders of the Series B Preferred Stock and all other such classes or series of parity shares shall share ratably in any such distribution of assets in proportion to the full liquidating distributions to which they would otherwise be respectively entitled. For such purposes, the consolidation or merger of us with or into any other entity, or the sale, lease or conveyance of all liabilities. Holdersor substantially all of common stock have no preemptive rightsour property or business, or a statutory share exchange shall not be deemed to purchase our common stock. There are no conversion rightsconstitute a voluntary or redemptioninvoluntary liquidation, dissolution or sinking fund provisions with respectwinding up of us.
The certificate of designation for the Series B Preferred Stock does not contain any provision requiring funds to be set aside to protect the common stock. Allliquidation preference of the outstanding shares of common stock are validly issued, fully paid and non-assessable.
Redemption
General
We may not redeem the Series B Preferred Stock
Upon the following:
Shares Beneficially Owned Prior To The Offering | Shares Beneficially Owned After The Offering | |||||||||||||||||||
| Name | Number | Percent(1) | Maximum Number Of Shares Being Offered | Number | Percent | |||||||||||||||
Paladin Capital Management, S.A. (1) | 90,000 | (2) | 1.9 | % | 1,390,000 | 0 | * | |||||||||||||
Unless full cumulative dividends on all Series B Preferred Stock and all parity shares shall have been or contemporaneously are declared and paid or declared and a sum sufficient for the payment thereof set apart for payment for all past dividend periods and the rulesthen current dividend period, no Series B Preferred Stock or parity shares shall be redeemed unless all outstanding Series B Preferred Stock and regulations thereunder, including, without limitation, Regulation Mparity shares are simultaneously redeemed; provided, however, that the foregoing shall not prevent the purchase or acquisition of Series B Preferred Stock or parity shares pursuant to a purchase or exchange offer made on the same terms to holders of all outstanding Series B Preferred Stock and parity shares. Furthermore, unless full cumulative dividends on all outstanding Series B Preferred Stock and parity shares have been or contemporaneously are declared and paid or declared and a sum sufficient for the payment thereof set apart for payment for all past dividend periods and the then current dividend period, we shall not purchase or otherwise acquire directly or indirectly any Series B Preferred Stock or parity shares (except by conversion into or exchange for our junior shares and parity shares).
From and after the redemption date (unless we default in payment of the redemption price), all dividends will cease to accumulate on the Series B Preferred Stock, such shares shall no longer be deemed to be outstanding, and all of your rights as a holder of shares of Series B Preferred Stock will terminate with respect to such shares, except the right to receive the redemption price and all accrued and unpaid dividends up to the redemption date.
Procedures
Notice of redemption will be mailed at least 30 days but not more than 90 days before the redemption date to each holder of record of Series B Preferred Stock at the address shown on our share transfer books. Each notice shall state:
| · | the redemption date, |
| · | the redemption price of $25.00 per share of Series B Preferred Stock, plus any accrued and unpaid dividends through the date of redemption, |
| · | the number of shares of Series B Preferred Stock to be redeemed, |
| · | the place or places where any certificates issued for Series B Preferred Stock other than through the DTC book entry described below, are to be surrendered for payment of the redemption price, |
| · | that dividends on the Series B Preferred Stock will cease to accrue on such redemption date, |
| · | that the shares of Series B Preferred Stock are being redeemed pursuant to our redemption right, and |
| · | any other information required by law or by the applicable rules of any exchange upon which the Series B Preferred Stock may be listed or admitted for trading. |
If fewer than all outstanding shares of Series B Preferred Stock are to be redeemed, the notice mailed to each such holder thereof shall also specify the number of shares of Series B Preferred Stock to be redeemed from each such holder.
Upon such notice of redemption:
| · | Dividends on the Series B Preferred Stock being redeemed shall cease to accrue, |
| · | Such redeemed shares of Series B Preferred Stock shall be no longer deemed to be outstanding, and |
| · | The rights of the holders of such Series B Preferred Stock shall cease (except the right to receive the redemption price (including accrued and unpaid dividends)). |
Upon issuing a notice of redemption, we shall deposit with our registrar and transfer agent the redemption price (including accrued and unpaid dividends) and give the registrar and transfer agent irrevocable instructions and authority to pay such amount to any holder of the Series B Preferred Stock properly redeeming its shares. For any Series B Preferred Stock is held through DTC book entry, on or prior to the redemption date, the registrar and transfer agent shall deposit the redemption price (including accrued and unpaid dividends) of the Series B Preferred Stock so called for redemption with DTC in trust for the nominee holders thereof. Any interest or other earnings earned on the redemption price (including all accrued and unpaid dividends) deposited with a bank or trust company will be paid to us. Any monies so deposited that remain unclaimed by the holders of the Series B Preferred Stock at the end of two years after the redemption date will be returned to us by the registrar and transfer agent.
After the redemption date, the redeemed shares of the Series B Preferred Stock shall not be considered outstanding for purposes of voting or determining shares entitled to vote on any matter on or after the redemption date.
On or after the redemption date, each holder of shares of Series B Preferred Stock that holds a certificate other than through the DTC book entry described below must present and surrender each certificate representing his Series B Preferred Stock to us at the place designated in the applicable notice and thereupon the redemption price of such shares will be paid to or on the order of the person whose name appears on such certificate representing the Series B Preferred Stock as the owner thereof, each surrendered certificate will be canceled and the shares will be retired and restored to the status of undesignated, authorized shares of preferred stock.
If we redeem any shares of Series B Preferred Stock and if the redemption date occurs after a dividend record date and on or prior to the related dividend payment date, the dividend payable on such dividend payment date with respect to such shares called for redemption shall be payable on such dividend payment date to the holders of record at the close of business on such dividend record date, and shall not be payable as part of the redemption price for such shares.
Voting Rights
Except as indicated below, the holders of Series B Preferred Stock have no voting rights.
If and whenever cash dividends on any outstanding Series B Preferred Stock have not been paid in full for any quarterly dividend period for any six consecutive or non-consecutive quarterly periods, whether or not earned or declared, the number of directors then constituting our board of directors will increase by two, and the holders of Series B Preferred Stock, voting together as a class with the holders of any other parity shares upon which like voting rights have been conferred (any such other series, being “voting preferred shares”), will have the right to elect two additional directors to serve on our board of directors at any meeting of stockholders called for the purpose of electing directors until all such dividends and all dividends for the current quarterly period on the Series B Preferred Stock and such other voting preferred shares have been paid or declared and paid in full. The term of office of all directors so elected will terminate with the termination of such voting rights, provided however that such voting rights shall be reinstated upon any subsequent failure to pay six consecutive or non-consecutive quarterly dividends.
The approval of holders of a majority of the outstanding Series B Preferred Stock is required in order to:
| · | amend our articles of incorporation if such amendment materially and adversely affects the rights, preferences or voting power of the holders of the Series B Preferred Stock or the voting preferred shares, provided that the creation of a class of parity shares or an increase of the authorized number of Series B Preferred Stock shall be deemed to not materially or adversely affect the rights, preferences or voting power of the holders of Series B Preferred Stock so long as all quarterly dividend payments have been paid in full; |
| · | authorize, reclassify, create, or increase the authorized amount of any class of stock having rights senior to the Series B Preferred Stock with respect to the payment of dividends or amounts upon liquidation, dissolution or winding up. |
The foregoing voting provisions will not apply if, at or prior to the time when the act with respect to which such vote would otherwise be required will be effected, all outstanding Series B Preferred Stock have been redeemed in accordance with their terms or called for redemption in accordance with their terms and sufficient funds shall have been deposited in trust to effect such redemption.
Except as provided above, the holders of Series B Preferred Stock are not entitled to vote.
Book-Entry Procedures
The Depository Trust Company & Clearing Corporation, which we refer to as DTC, will act as securities depositary for the Series B Preferred Stock. We will issue one or more fully registered global securities certificates in the name of DTC’s nominee, Cede & Co. These certificates will represent the total aggregate number of shares of Series B Preferred Stock. We will deposit these certificates with DTC or a custodian appointed by DTC. We will not issue certificates to you for the Series B Preferred Stock that you purchase, unless DTC’s services are discontinued as described below.
Title to book-entry interests in the Series B Preferred Stock will pass by book-entry registration of the transfer within the records of DTC, as the case may be, in accordance with their respective procedures. Book-entry interests in the securities may be transferred within DTC in accordance with procedures established for these purposes by DTC.
Each person owning a beneficial interest in the Series B Preferred Stock must rely on the procedures of DTC and the participant through which such person owns its interest to exercise its rights as a holder of the Series B Preferred Stock.
DTC has advised us that it is a limited-purpose trust company organized under the New York Banking Law, a member of the Federal Reserve System, a “clearing corporation” within the meaning of the New York Uniform Commercial Code, and a “clearing agency” registered under the provisions of Section 17A of the Exchange Act. DTC holds securities that its participants, referred to as “Direct Participants”, deposit with DTC. DTC also facilitates the settlement among Direct Participants of securities transactions, such as transfers and pledges, in deposited securities through electronic computerized book-entry changes in Direct Participants’ accounts, thereby eliminating the need for physical movement of securities certificates. Direct Participants include securities brokers and dealers, banks, trust companies, clearing corporations, and certain other organizations. DTC is owned by a number of its Direct Participants and by the New York Stock Exchange, Inc., the NYSE Amex, and the Financial Industry Regulatory Authority, Inc. Access to the DTC system is also available to others such as securities brokers and dealers, banks and trust companies that clear through or maintain a custodial relationship with a Direct Participant, either directly or indirectly, referred to as “Indirect Participants.” The rules applicable to DTC and its Direct and Indirect Participants are on file with the SEC.
When you purchase the Series B Preferred Stock within the DTC system, the purchase must be made by or through a Direct Participant. The Direct Participant will receive a credit for the Series B Preferred Stock on DTC’s records. You, as the actual owner of the Series B Preferred Stock, are the “beneficial owner.” Your beneficial ownership interest will be recorded on the Direct and Indirect Participants’ records, but DTC will have no knowledge of your individual ownership. DTC’s records reflect only the identity of the Direct Participants to whose accounts Series B Preferred Stock is credited.
You will not receive written confirmation from DTC of your purchase. The Direct or Indirect Participants through whom you purchased the Series B Preferred Stock should send you written confirmations providing details of your transactions, as well as periodic statements of your holdings. The Direct and Indirect Participants are responsible for keeping an accurate account of the holdings of their customers like you.
Transfers of ownership interests held through Direct and Indirect Participants will be accomplished by entries on the books of Direct and Indirect Participants acting on behalf of the beneficial owners.
The laws of some states may require that specified purchasers of securities take physical delivery of the Series B Preferred Stock in definitive form. These laws may impair the ability to transfer beneficial interests in the global certificates representing the Series B Preferred Stock.
Conveyance of notices and other communications by DTC to Direct Participants, by Direct Participants to Indirect Participants, and by Direct Participants and Indirect Participants to beneficial owners will be governed by arrangements among them, subject to any statutory or regulatory requirements as may be in effect from time to time.
We understand that, under DTC’s existing practices, in the event that we request any action of holders, or an owner of a beneficial interest in a global security such as you desires to take any action which a holder is entitled to take under our articles of incorporation, as amended or supplemented, DTC would authorize the Direct Participants holding the relevant shares to take such action, and those Direct Participants and any Indirect Participants would authorize beneficial owners owning through those Direct and Indirect Participants to take such action or would otherwise act upon the instructions of beneficial owners owning through them.
Redemption notices will be sent to Cede & Co. If less than all of the outstanding shares of Series B Preferred Stock are being redeemed, DTC will reduce each Direct Participant’s holdings of Series B Preferred Stock in accordance with its procedures.
In those instances where a vote is required, neither DTC nor Cede & Co. itself will consent or vote with respect to the Series B Preferred Stock. Under its usual procedures, DTC would mail an omnibus proxy to us as soon as possible after the record date. The omnibus proxy assigns Cede & Co.’s consenting or voting rights to those Direct Participants to whose accounts the Series B Preferred Stock is credited on the record date, which are identified in a listing attached to the omnibus proxy.
Dividends on the Series B Preferred Stock will be made directly to DTC. DTC’s practice is to credit participants’ accounts on the relevant payment date in accordance with their respective holdings shown on DTC’s records unless DTC has reason to believe that it will not receive payment on that payment date.
Payments by Direct and Indirect Participants to beneficial owners such as you will be governed by standing instructions and customary practices, as is the case with securities held for the accounts of customers in bearer form or registered in “street name.” These payments will be the responsibility of the participant and not of DTC, us or any agent of ours.
DTC may discontinue providing its services as securities depositary with respect to the Series B Preferred Stock at any time by giving reasonable notice to us. Additionally, we may decide to discontinue the book-entry only system of transfers with respect to the Series B Preferred Stock. In that event, we will print and deliver certificates in fully registered form for the Series B Preferred Stock. If DTC notifies us that it is unwilling to continue as securities depositary, or if it is unable to continue or ceases to be a clearing agency registered under the Exchange Act which may limitand a successor depositary is not appointed by us within 90 days after receiving such notice or becoming aware that DTC is no longer so registered, we will issue the timingSeries B Preferred Stock in definitive form, at our expense, upon registration of purchasestransfer of, or in exchange for, such global security.
According to DTC, the foregoing information with respect to DTC has been provided to the financial community for informational purposes only and salesis not intended to serve as a representation, warranty or contract modification of any kind.
Initial settlement for the Series B Preferred Stock will be made in immediately available funds. Secondary market trading between DTC’s participants will occur in the ordinary way in accordance with DTC’s rules and will be settled in immediately available funds using DTC’s Same-Day Funds Settlement System.
| 56 |
UNDERWRITING
Under the terms and subject to the conditions contained in an underwriting agreement between us and the underwriters, we have agreed to issue and sell to the public through the underwriters, and the underwriters have agreed to offer and sell, 300,000 shares of our Series B Preferred Stock, on a best-efforts basis.
The underwriting agreement provides that the obligation of the underwriters to offer and sell the shares of Series B Preferred Stock, on a best-efforts basis, is subject to certain conditions precedent, including but not limited to delivery of legal opinions and auditor comfort letters. The underwriters are under no obligation to purchase any shares of Series B Preferred Stock for their own accounts. As a “best-efforts” offering, there can be no assurance that the offering contemplated hereby will ultimately be consummated. The underwriters may, but are not obligated to, retain other selected dealers that are qualified to offer and sell the shares and that are members of the Financial Industry Regulatory Authority.
The underwriters propose to offer the shares of Series B Preferred Stock to investors at the public offering price set forth on the cover of this prospectus. There is no arrangement for funds to be received in escrow, trust or similar arrangement. In connection with the offer and sale of the Series B Preferred Stock by the underwriters, we will pay the underwriters a collective amount equal to [·] % of the gross proceeds received by us in connection with the sale of the shares of Series B Preferred Stock, which will be deemed underwriting commissions.
The following table summarizes the compensation and estimated expenses we will pay:
| Per Share | Total | |||
| Public offering price | $ – $ | $ – $ | ||
| Underwriting commission paid by us | $ – $ | $ – $ | ||
| Proceeds, before expenses, to us | $ – $ | $ – $ |
In connection with the successful completion of this offering, for the price of $50 each, the underwriters may purchase a five-year warrant to purchase shares of our common stock by the Selling Stockholder and any other participating person. Regulation M may also restrict the ability of any person engaged in the distributionequal to [●]% of the shares sold in this offering at an exercise price of % of the closing price of our common stock to engage in market-making activities with respect to such shares. Allon the date of the foregoingunderwriting agreement. The warrants that the underwriters may affectpurchase described in this paragraph will contain demand registration rights. We also granted Northland Capital Markets and Euro Pacific Capital a right of first refusal to participate in any subsequent offering or placement of our securities that takes place during the marketabilityterm of our engagement with Northland Capital Markets and Euro Pacific Capital or within twelve months thereafter.
We have also agreed to pay the underwriters’ reasonable out-of-pocket expenses (including fees and expense of the sharesunderwriters’ counsel) incurred by the underwriters in connection with this offering up to $[·]. In addition, we estimate that our share of our common stockthe total expenses of this offering, excluding underwriting discounts and commissions referred to above and payment of the abilityunderwriters’ expenses referred to below, will be approximately $ [·]. Except as disclosed in this prospectus, the underwriter has not received and will not receive from us any other item of any personcompensation or entityexpense in connection with this offering considered by the Financial Industry Regulatory Authority to engage in market-making activities with respect to our common stock.
Indemnification of Underwriters
We will pay all expenses of the registration of these shares, including, without limitation, Securities and Exchange Commission filing fees and expenses of compliance with state securities or “blue sky” laws; provided, however, that the Selling Stockholder will pay all underwriting discounts, commissions and concessions and brokers’ or agents’ commissions and concessions or selling commissions and concessions, if any. We have agreed to indemnify the Selling Stockholderunderwriters against liabilities, including some liabilities under the Securities Act, or the Selling Stockholder will be entitled to contribution. We may be indemnified by the Selling Stockholder against civil liabilities, including liabilities under the Securities Act of 1933 and liabilities arising from breaches of our representations and warranties contained in the underwriting agreement. If we are unable to provide this indemnification, we will contribute to payments the underwriters may be required to make in respect of those liabilities.
The underwriters and their affiliates may provide from time to time in the future certain financial advisory, investment banking and other services for us in the ordinary course of their business, for which they have received and may continue to receive customary fees and commissions. In addition, from time to time, the underwriters and their affiliates may effect transactions for their own accounts or the accounts of customers, and hold on behalf of themselves or their customers, long or short positions in our debt or equity securities or loans, and may do so in the future.
No Sales of Similar Securities
The underwriters have required all of our directors and officers to agree not to offer, sell, agree to sell, directly or indirectly, or otherwise dispose of any shares of capital stock or any securities convertible into or exchangeable for shares of capital stock without the prior written consent of Northland Securities, Inc. for a period of 90 days after the date of the final prospectus supplement.
The restrictions described in the immediately preceding paragraph do not apply to certain items, including transfers as a bona fide gift or gifts, transfers by will or intestate succession, or to any trust for the direct or indirect benefit of the director or officer or his or her immediate family, provided that in each case any such recipient agrees to be bound by the terms of the restrictions described above, and transfers in connection with the exercise of any stock options that expire during the period described above, to the extent necessary to fund the exercise price of the stock options and any withholding taxes resulting from such exercise.
We have agreed that for a period of 90 days after the date of this prospectus, we will not, without the prior written consent of Northland Securities, Inc., offer, sell or otherwise dispose of any shares of capital stock, except for the shares of Series B Preferred Stock offered in this offering, awards to acquire shares of our common stock granted pursuant to our equity incentive plans existing on the date of the underwriting agreement, and shares of common stock issuable in connection with such awards.
The 90-day restricted period in all of the agreements described above is subject to extension if (i) during the last 17 days of the restricted period we issue an earnings release or material news or a material event relating to us occurs or (ii) prior to the expiration of the restricted period, we announce that we will release earnings results during the 16-day period beginning on the last day of the lock-up period, in which case the restrictions imposed in these lock-up agreements shall continue to apply until the expiration of the 18-day period beginning on the issuance of the earnings release or the occurrence of the material news or material event, unless Northland Securities, Inc. waives the extension in writing.
Stamp Taxes
If you purchase shares of Series B Preferred Stock offered in this prospectus, you may arisebe required to pay stamp taxes and other charges under the laws and practices of the country of purchase, in addition to the offering price listed on the cover page of this prospectus.
Foreign Regulatory Restrictions on Purchase of the Series C Preferred Stock
No action may be taken in any jurisdiction other than the United States that would permit a public offering of the Series B Preferred Stock or the possession, circulation or distribution of this prospectus in any jurisdiction where action for that purpose is required. Accordingly, the Series B Preferred Stock may not be offered or sold, directly or indirectly, and neither the prospectus nor any other offering material or advertisements in connection with the Series B Preferred Stock may be distributed or published in or from any written information furnished tocountry or jurisdiction except under circumstances that will result in compliance with any applicable rules and regulations of any such country or jurisdiction.
Additional Information
In the ordinary course of its business, the underwriters and their affiliates may actively trade or hold our securities for their own accounts or for the accounts of customers and, accordingly, may at any time hold long or short positions in our securities. The underwriters and their affiliates may in the future perform various financial advisory and investment banking services for us, for which they will receive customary fees and expense.
North and Captital Markets is the trade name for certain capital markets and investment banking services of Northland Securities, Inc., member FINRA/SIPC.
This prospectus may be made available on web sites maintained by the Selling Stockholder specifically for use in this prospectusor weunderwriters and the underwriters may be entitled to contribution.
LEGAL MATTERS
The validity of the issuance of the shares of common stocksecurities offered hereby will beby this prospectus and certain tax matters have been passed upon for us by Reicker, Pfau, Pyle & McRoy LLP, Santa Barbara, California. The underwriters have been represented in connection with this offering by Faegre Baker Daniels LLP, Minneapolis, Minnesota.
EXPERTS
The financial statements of EnerJex as of December 31, 2012 and 2011, and for each of the Law Officetwo years in the period ended December 31, 2012, included in the prospectus, which is part of Anthony N. DeMint, Las Vegas, Nevada.
The financial statements of Black Raven as of December 31, 2012 and 2011, and for each of the two years in the period ended December 31, 2012, included in this registration statement of EnerJex and the related prospectus of EnerJex and Black Raven have been audited by L.L. Bradford, LLC, independent registered public accounting firm, as set forth in their report appearing elsewhere herein, and are included in reliance upon such report given on the authority of such firm as experts in accounting and auditing.
The information incorporated herein regardingincluded in this prospectus, including the annexes, as of December 31, 2011 and 2012 relating to EnerJex’s estimated quantities of oil and natural gas reserves and their present value is based on estimates of the reserves and present valuesderived from reserve reports prepared by or derived from estimates prepared by Miller and Lents, Ltd., independent petroleum engineers and geologists. The reserveMHA Petroleum Consultants LLC. This information is incorporated hereinincluded in this proxy statement/information statement/prospectus in reliance upon the authority of saidsuch firm as an expert with respect to such report.
WHERE YOU CAN FIND MORE INFORMATION
We are a public company and file annual, quarterly and current reports, proxy statements and other information with the Securities and Exchange Commission. You may read and copy any document we file at the SEC's Public Reference Room at 100 F Street, N.E., Room 1580, Washington, D.C. 20549. You can request copies of these documents by writing to the SEC and paying a fee for the copying cost. Please call the SEC at 1-800-SEC-0330 for more information about the operation of the public reference room. Our SEC filings are also available to the public at the SEC's web site at http://www.sec.gov.
Certain reports and documents have been incorporated by reference in the prospectus contained in this registration statement on Form S-1. We will provide these reports upon written or oral request at no cost. You may contact us with such requests at: EnerJex Resources, Inc., 4040 Broadway, Suite 508, San Antonio, TX 78209, Attn: Chief Executive Officer or call us at (210) 451-5545.
In addition, we maintain a website that contains information, including copies of reports, proxy statements and other information it files with the SEC. The address of our website iswww.enerjex.com. Information contained on our website or that can be accessed through our website does not constitute a part of this proxy statement/information statement/prospectus. We have included our website addresses only as inactive textual references and does not intend it to be an active link to its website.
We have filed with the SEC a registration statement on Form S-1, which includes exhibits, schedules and amendments, under the Securities Act, with the SEC with respect to the common stock offered by this prospectus. Thisoffering of our securities. Although this prospectus, does not include allwhich forms a part of the registration statement, contains all material information containedincluded in the registration statement, orparts of the exhibitsregistration statement have been omitted as permitted by rules and schedules filed therewith. You shouldregulations of the SEC. We refer you to the registration statement and its exhibits for additional information. Whenever we make reference infurther information about us, our securities and this prospectus to any of our contracts, agreements or other documents, the references are not necessarily complete and you should refer to the exhibits attached to theoffering. The registration statement for copies of the actual contract, agreement orand its exhibits, as well as our other document.
No dealer, salesperson or any other person is authorized to give any information or make any representations in connection with this offering other than those contained in this prospectus and, if given or made, the information or representations must not be relied upon as having been authorized by us. This prospectus does not constitute an offer to sell or a solicitation of our annual reportan offer to buy any security holders, including audited financial statements, at no charge upon receiptother than the securities offered by this prospectus, or an offer to sell or a solicitation of your written requestan offer to us at EnerJex Resources, Inc., 27 Corporate Woods, Suite 350, 10975 Grandview Drive, Overland Park, Kansas 66210.
INDEX TO FINANCIAL STATEMENTS
| Black Raven Energy, Inc. and Subsidiaries | Page |
| Index to Financial Statements | F-1 |
| Report of Independent Registered Public Accounting Firm | |
| Consolidated Balance Sheets at | |
| Consolidated Statements of Operations for the | |
| Consolidated Statement of | |
| Consolidated Statement of Cash Flows for the | |
| Notes to Consolidated Financial Statements | |
| Black Raven Energy, Inc. and Subsidiaries – Six Month Financial Statements as of June 30, 2013 | |
| Balance Sheet | F-25 |
| Statement of Operations and Deficit | F-27 |
| Statement of Cash Flows | F-30 |
| EnerJex Resources, Inc. and Subsidiaries | |
| Report of Independent Registered Public Accounting Firm | F-31 |
| Consolidated Balance Sheets at December 31, 2012 and December 31, 2011 | F-32 |
| Consolidated Statements of Operations for the Year Ended December 31, 2012 and December 31, 2011 | F-33 |
| Consolidated Statement of Stockholders' Equity(Deficit) for the Year Ended December 31, 2012 and December 31, 2011 | F-34 |
| Consolidated Statement of Cash Flows for the Year Ended December 31, 2012 and December 31, 2011 | F-35 |
| Notes to Consolidated Financial Statements | F-36 |
| EnerJex Resources, Inc. and Subsidiaries – Nine Month Financial Statements as of September 30, 2013 | |
| Balance Sheet | F-47 |
| Statement of Operations and Deficit | F-48 |
| Statement of Cash Flows | F-49 |
| Black Raven Energy, | ||
| Inc. and Subsidiaries | ||
| Consolidated Financial Statements as of and for the | ||
| Years Ended December 31, 2012 and 2011, and | ||
| Independent Auditors’ Report |
Independent Auditor’s Report
To the Board of Independent Registered Public Accounting Firm
Black Raven Energy, Inc.
Denver, Colorado
We have audited the accompanying consolidated balance sheetsheets of EnerJex Resources,Black Raven Energy, Inc. and subsidiaries (the “Company”) as of MarchDecember 31, 20092012 and 20082011, and the related consolidated statements of operations, stockholders’ equity (deficit),deficit, and cash flows for each of the two years in the two-year period ended MarchDecember 31, 2009.2012. These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such financial statements present fairly, in all material respects, the financial position of Black Raven Energy, Inc. and subsidiaries at December 31, 2012 and 2011, and the results of their operations and their cash flows for each of the two years in the period ended December 31, 2012, in conformity with accounting principles generally accepted in the United States of America.
The accompanying financial statements have been prepared assuming that the Company will continue as a going concern. As discussed in Note 1 to the financial statements, the Company’s recurring losses, negative cash flows from operations and stockholders’ deficit raise substantial doubt about its ability to continue as a going concern. Management’s plans concerning these matters are also discussed in Note 1 to the financial statements. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.
L.L. Bradford & Company, LLC
Las Vegas, Nevada
August 2, 2013
Black Raven Energy, Inc.
Consolidated Balance Sheets
(In thousands)
| December 31, 2012 | December 31, 2011 | |||||||
| Assets | ||||||||
| Current assets: | ||||||||
| Cash and cash equivalents | $ | 1,719 | $ | 1,865 | ||||
| Restricted cash (Note 3) | 249 | 18,548 | ||||||
| Accounts receivable, net of allowance ($2 and $2 respectively) | 731 | 765 | ||||||
| Derivative asset (Note 13) | 178 | 30 | ||||||
| Inventory | 27 | 139 | ||||||
| Prepaid expenses | 144 | 256 | ||||||
| Total current assets | 3,048 | 21,603 | ||||||
| Oil and gas properties accounted for under the successful efforts method of accounting: | ||||||||
| Proved properties | 22,944 | 18,886 | ||||||
| Unproved leaseholds | 54 | 36 | ||||||
| Wells-in-progress | 1,661 | 1,723 | ||||||
| Total oil and gas properties | 24,659 | 20,645 | ||||||
| Less: accumulated depreciation, depletion and amortization | (2,707 | ) | (1,643 | ) | ||||
| Net oil and gas properties | 21,952 | 19,002 | ||||||
| Gathering and other property and equipment | 3,444 | 3,198 | ||||||
| Less: accumulated depreciation and amortization | (1,182 | ) | (1,078 | ) | ||||
| Net gathering and other property and equipment | 2,262 | 2,120 | ||||||
| Other non-current assets: | ||||||||
| Derivative asset (Note 13) | 185 | 192 | ||||||
| Deferred financing costs | 2,631 | 3,366 | ||||||
| Restricted cash (Note 3) | 450 | 450 | ||||||
| Other non-current assets | 632 | 634 | ||||||
| Total other non-current assets | 3,818 | 4,642 | ||||||
| TOTAL ASSETS | $ | 31,160 | $ | 47,367 | ||||
The accompanying notes are an integral part of these consolidated financial statements.
Black Raven Energy, Inc.
Consolidated Balance Sheets (Continued)
(In thousands, except share amounts)
| December 31, 2012 | December 31, 2011 | |||||||
| Liabilities and Stockholders’ Deficit | ||||||||
| Current liabilities: | ||||||||
| Accounts payable | $ | 2,290 | $ | 6,915 | ||||
| Accrued expenses and other current liabilities | 2,054 | 909 | ||||||
| Advances from Atlas (Note 3) | 150 | 14,056 | ||||||
| Current portion of long-term debt | 36 | 9 | ||||||
| Total current liabilities | 4,530 | 21,889 | ||||||
| Secured notes and debentures, net of discount | 37,716 | 34,823 | ||||||
| Notes payable, net of current portion | 84 | 28 | ||||||
| Asset retirement obligations | 1,192 | 1,034 | ||||||
| Total liabilities | 43,522 | 57,774 | ||||||
| Commitments and Contingencies (Note 8) | ||||||||
| Stockholders’ deficit | ||||||||
| Common stock, par value $.001, 150,000,000 shares authorized; 17,601,774 and 17,129,296 issued and outstanding, respectively | 17 | 17 | ||||||
| Additional paid-in-capital | 32,038 | 30,943 | ||||||
| Accumulated deficit | (44,417 | ) | (41,367 | ) | ||||
| Total stockholders’ deficit | (12,362 | ) | (10,407 | ) | ||||
| TOTAL LIABILITIES AND STOCKHOLDERS’ DEFICIT | $ | 31,160 | $ | 47,367 | ||||
The accompanying notes are an integral part of these consolidated financial statements.
Black Raven Energy, Inc.
Consolidated Statements of Operations
(In thousands)
| Years Ended December 31, | ||||||||
| 2012 | 2011 | |||||||
| Operating revenue: | ||||||||
| Oil and gas sales | $ | 4,023 | $ | 1,388 | ||||
| Gain on sale of oil and gas properties | 2,963 | 4,281 | ||||||
| Management revenue | 60 | — | ||||||
| Total operating revenue | 7,046 | 5,669 | ||||||
| Operating expenses: | ||||||||
| Oil and gas production expense | 1,679 | 762 | ||||||
| Exploration expense | 13 | 9 | ||||||
| Depreciation, depletion, amortization and accretion | 1,386 | 550 | ||||||
| After pay-out interest conveyed for services rendered | — | 1,522 | ||||||
| General and administrative | 2,001 | 2,119 | ||||||
| Total operating expenses | 5,079 | 4,962 | ||||||
| Operating income | 1,967 | 707 | ||||||
| Other income (expense): | ||||||||
| Interest and other income | 114 | 69 | ||||||
| Realized and unrealized gain on derivative contracts | 207 | 317 | ||||||
| Gain on disposal of assets | 18 | — | ||||||
| Interest expense | (5,356 | ) | (3,433 | ) | ||||
| Total other expense | (5,017 | ) | (3,047 | ) | ||||
| Loss before income taxes | (3,050 | ) | (2,340 | ) | ||||
| Income tax expense | — | (54 | ) | |||||
| Net loss | $ | (3,050 | ) | $ | (2,394 | ) | ||
The accompanying notes are an integral part of these consolidated financial statements.
Black Raven Energy, Inc.
Consolidated Statements of Stockholders’ Deficit
Years Ended December 31, 2012 and 2011
(In thousands)
| Additional | Total | |||||||||||||||||||
| Common | Paid - In | Accumulated | Stockholders’ | |||||||||||||||||
| Shares | Amount | Capital | Deficit | Deficit | ||||||||||||||||
| Balance at January 1, 2011 | 16,660,965 | $ | 17 | $ | 29,744 | $ | (38,973 | ) | $ | (9,212 | ) | |||||||||
| Issuance of shares | 468,331 | — | 942 | — | 942 | |||||||||||||||
| Share-based compensation | — | — | 257 | — | 257 | |||||||||||||||
| Net loss | — | — | — | (2,394 | ) | (2,394 | ) | |||||||||||||
| Balance at December 31, 2011 | 17,129,296 | 17 | 30,943 | (41,367 | ) | (10,407 | ) | |||||||||||||
| Issuance of shares | 472,478 | — | 945 | — | 945 | |||||||||||||||
| Share-based compensation | — | — | 150 | — | 150 | |||||||||||||||
| Net loss | — | — | — | (3,050 | ) | (3,050 | ) | |||||||||||||
| Balance at December 31, 2012 | 17,601,774 | $ | 17 | $ | 32,038 | $ | (44,417 | ) | $ | (12,362 | ) | |||||||||
The accompanying notes are an integral part of these consolidated financial statements.
Black Raven Energy, Inc.
Consolidated Statements of Cash Flows
(In thousands)
| Years Ended December 31, | ||||||||
| 2012 | 2011 | |||||||
| Cash flows from operating activities | ||||||||
| Net loss | $ | (3,050 | ) | $ | (2,394 | ) | ||
| Adjustments to reconcile net loss to net cash used in operating activities: | ||||||||
| Gain on sale of oil and gas properties | (2,963 | ) | (4,281 | ) | ||||
| Depreciation, depletion, amortization and accretion | 1,386 | 550 | ||||||
| Amortization of debt issuance costs | 734 | 321 | ||||||
| Amortization of debt discount | 590 | 246 | ||||||
| Share-based compensation expense | 150 | 257 | ||||||
| After pay-out interest conveyed for services rendered | — | 1,522 | ||||||
| Non-cash interest expense | 1,423 | 942 | ||||||
| Gain on sale of assets and other | (18 | ) | — | |||||
| Unrealized (gain) loss on derivative assets | (141 | ) | (222 | ) | ||||
| Changes in assets and liabilities: | ||||||||
| Accounts receivable | 34 | (763 | ) | |||||
| Inventory | 113 | (86 | ) | |||||
| Prepaid expenses | 112 | 4 | ||||||
| Other non-current assets | 2 | (482 | ) | |||||
| Restricted cash (Note 3) | 18,299 | (12,911 | ) | |||||
| Advances from Atlas | (12,541 | ) | 8,147 | |||||
| Accounts payable | (4,952 | ) | 4,929 | |||||
| Accrued expenses and other current liabilities | (220 | ) | 1,798 | |||||
| Other non-current liabilities | (9 | ) | — | |||||
| Net cash from operating activities | (1,051 | ) | (2,423 | ) | ||||
| Cash flows from investing activities | ||||||||
| Property acquisitions | — | (16,889 | ) | |||||
| Capital expenditures | (4,086 | ) | (1,655 | ) | ||||
| Restricted cash – interest reserve | — | (450 | ) | |||||
| Proceeds from Farmout Agreement (Note 3) | 3,060 | 8,040 | ||||||
| Proceeds from sale of assets | 23 | — | ||||||
| Net cash from investing activities | (1,003 | ) | (10,954 | ) | ||||
| Cash flows from financing activities | ||||||||
| Proceeds from loans | 2,608 | 18,037 | ||||||
| Deferred financing costs | — | (1,743 | ) | |||||
| Repayment of loans | (700 | ) | (2,000 | ) | ||||
| Net cash from financing activities | 1,908 | 14,294 | ||||||
| Net increase (decrease) in cash | (146 | ) | 917 | |||||
| Cash and cash equivalents—beginning of year | 1,865 | 948 | ||||||
| Cash and cash equivalents—end of year | $ | 1,719 | $ | 1,865 | ||||
| Supplemental disclosure of cash flow activity | ||||||||
| Cash paid for interest (net of amounts capitalized) | $ | 1,597 | $ | 1,735 | ||||
| Supplemental schedule of non-cash investing and financing activities | ||||||||
| Accrued capital expenditures | $ | 1,207 | $ | 609 | ||||
| Conversion of interest to debt | $ | 477 | $ | 180 | ||||
| Overriding royalty interest conveyed for financing | $ | — | $ | 2,394 | ||||
The accompanying notes are an integral part of these consolidated financial statements.
BLACK RAVEN ENERGY, INC.
Notes to Consolidated Financial Statements
December 31, 2012 and 2011
Note 1 – Business, Going Concern and Significant Transactions
Business
Black Raven Energy, Inc. and its wholly-owned subsidiary, PRB Gathering, Inc. (“PRB Gathering”) (together, the “Company”), operate as an independent energy company engaged in the acquisition, exploitation, development and production of natural gas and oil in the Rocky Mountain region of the United States.
Going Concern
The accompanying consolidated financial statements have been prepared assuming the Company will continue as a going concern. As shown in the accompanying financial statements, the Company continues to report a shareholders’ deficit totaling $12.4 million as of December 31, 2012. Additionally, the Company recorded negative cash flows from operations totaling $1.1 million for the year ended December 31, 2012. Cash and cash equivalents on hand and internally generated cash flows may not be sufficient to execute the Company’s business plan. Future bank financings, asset sales, joint ventures, farmouts or other equity or debt financings will be required to fund the Company’s debt service, working capital requirements, planned drilling, potential acquisitions and other capital expenditures. These conditions raise substantial doubt about the Company’s ability to continue as a going concern. The consolidated financial statements do not include any adjustments that may result from the outcome of this uncertainty.
Management’s plans to mitigate the substantial doubt about the Company’s ability to continue as a going concern include finding a strategic partner and merging with that partner as further discussed in Note 15.
Significant Transactions
On June 6, 2011, the Company acquired from Diamond Operating all of its interests in the Marks Butte area of Sedgwick County, Colorado. The purchase price was $98,500, and included title and interest in all oil and gas leases, all easements, rights-of-way, a 100% working interest in two shut-in wells, 6.15 miles of pipeline and a compressor station with a tap into the Trailblazer Pipeline. We acquired the assets primarily to utilize the tap for potential drilling in the East Marks Butte area.
On July 27, 2011, the Company purchased 80% of the Adena Properties. The Adena Properties consist of an existing waterflood in the J Sand and a conventional oil field in the D Sand. In addition, there is a gas cap in the J Sand that can be produced in the future. The acquisition consists of an 80% working interest in 18,760 gross acres for a purchase price of $15.75 million, subject to adjustments for production after the effective date and other matters. The effective date of the acquisition was April 1, 2011.
On December 6, 2011, the Company acquired the remaining 20% working interest in the Adena Properties for a purchase price of $1.7 million in cash, subject to post-closing adjustments as set forth in the agreement. The acquisition was effective July 1, 2011.
We entered into an agreement with a strategic partnerwho provided due diligence services in connection with the acquisition of the Adena Properties. In addition, our strategic partner will provide future geological, engineering, and management consulting services associated with the operation of the Adena Properties. As compensation for the due diligence services performed for the Company, our partner earned 30% of our working interest after payout of all costs, including financing costs. In connection with the consulting arrangement, our partner will earn monthly consulting fees as future services are performed based on the production realized from the Adena Properties. No significant consulting fees were paid during 2012 or 2011.
Note 2 - Summary of Significant Accounting Policies
Basis of Presentation - The consolidated financial statements include the accounts of the Company and its subsidiaries. These statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”). All inter-company transactions have been eliminated. In connection with the preparation of the consolidated financial statements, the Company evaluated subsequent events after the balance sheet date of December 31, 2012, through August 1, 2013.
Use of Estimates - The preparation of financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Some specific examples of such estimates include the allowance for doubtful accounts receivable, accrued expenses, accrued revenue, asset retirement obligations, purchase price allocation, valuation of interests conveyed, determining the remaining economic lives and carrying values of property and equipment, and the estimates of gas reserves that affect the depletion calculation and impairments for gas properties and other long-lived assets. In addition, the Company uses assumptions to estimate the fair value of share-based compensation. The Company believes its estimates and assumptions are reasonable; however, actual results may differ from its estimates.
Cash and Cash Equivalents - The Company considers all highly liquid instruments purchased with an original maturity of three months or less to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value due to the short-term nature of these instruments. The Company continually monitors its positions with, and the credit quality of, the financial institutions with which it invests.
Restricted Cash — Restricted cash includes cash received from Atlas restricted for drilling activities in connection with oil and gas properties subject to the Farmout Agreement. See Note 3 for further discussion of the Farmout Agreement. Non-current restricted cash includes a reserve account required pursuant to the terms of the debt issued upon acquisition of the Adena Properties (See Note 9).
Accounts Receivable - Trade accounts receivable are recorded at the invoiced amount. The Company assesses credit risk and allowance for doubtful accounts on a customer specific basis. The Company had an allowance for doubtful accounts of $2,000 at December 31, 2012 and 2011.
The Company grants credit in the normal course of business to customers in the United States. The Company periodically performs credit analyses and monitors the financial condition of its customers to reduce credit risk. Management periodically reviews accounts receivable aging reports to assess credit risks, and if appropriate, also reviews updated credit information to further assess such risk. In the event that management determines the customers’ accounts receivable collectability as less than probable, management reduces the carrying amount by a valuation allowance that reflects management’s best estimate of the amount not collectible. Allowances for uncollectible accounts receivable are based on information available and historical experience. For information on the concentration of credit risk by customer in the years ended December 31, 2012 and 2011, see below.
Inventory - Inventory is recorded at cost. The Company periodically reviews the carrying cost of its inventories as compared to current market value for those inventories and adjusts its carrying value to the lower of cost or market. Inventory at December 31, 2012 and 2011 consisted primarily of tubing, and totaled $27,000 and $139,000, respectively.
Income Taxes — The Company recognizes deferred tax liabilities and assets based on the differences between the tax basis of assets and liabilities and their reported amounts in the consolidated financial statements that will result in taxable or deductible amounts in future years. In evaluating the ability to realize net deferred tax assets, the Company will take into account a number of factors, primarily relating to the Company’s ability to generate taxable income. The Company has recognized, before the valuation allowance, a net deferred tax asset attributable to the net operating losses for the years ended December 31, 2012 and 2011, respectively. FASB ASC Topic 740, “Income Taxes” (“ASC Topic 740”), requires that a valuation allowance be recorded against deferred tax assets unless it is more likely than not that the deferred tax asset will be utilized. As a result of this analysis, the Company has recorded a full valuation allowance against its net deferred tax asset.
The Company has adopted the uncertainty provisions of ASC Topic 740, which require the Company to recognize the impact of a tax position in its financial statements only if the technical merits of that position indicate that the position is more likely than not of being sustained upon audit. The Company recognizes potential accrued interest and penalties, if any, related to unrecognized tax benefits in income tax expense, which is consistent with the recognition of these items in prior reporting periods.
Revenue Recognition - Revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if the collectability of the revenue is probable. The Company derives revenue primarily from the sale of produced oil and natural gas. The Company reports revenue as the gross amount received before taking into account production taxes and transportation costs, which are reported as separate expenses. Revenue is recorded in the month the Company’s production is delivered to the purchaser, but payment is generally received between 30 and 90 days after the date of production. Revenues from the production of oil and gas properties in which the Company has an interest with other producers are recognized on the basis of the Company’s net working interest. At the end of each month, the Company calculates a revenue accrual based on the estimates of production delivered to or transported for the purchaser.
Property, Equipment - Gas Gathering and Other - Gathering assets, including compressor sites and pipelines, are recorded at cost and depreciated using the straight line method over the estimated useful lives of the assets, which range from ten to thirty years. Other property and equipment, such as office furniture, computer and related software and equipment, automobiles and leasehold improvements are recorded at cost. Depreciation is calculated using the straight-line method over the estimated useful lives of the assets or underlying leases, in respect to leasehold improvements, ranging from three to ten years.
Oil and Gas Producing Properties – The Company has elected to follow the successful efforts method of accounting for its oil and gas properties. Under this method of accounting, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well has found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the unsuccessful exploratory well are charged to expense. Exploratory dry hole costs are included in cash flows from investing activities as part of capital expenditures in the consolidated statements of cash flows. The cost of development wells, whether productive or not, is capitalized.
Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the unit-of-production amortization rate. A gain or loss is recognized for all other sales of proved properties. Unproved oil and gas property costs are transferred to proved oil and gas properties if the properties are determined to be productive and are assigned proved reserves. Proceeds from sales of partial interests in unproved properties are accounted for as a recovery of cost without recognizing gain until all costs are recovered. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts.
Depreciation, depletion, amortization and accretion (“DD&A”) of capitalized costs of proved oil and gas properties is determined on a field-by-field basis using the units-of-production method based upon proved reserves. The computation of DD&A takes into consideration restoration, dismantlement and abandonment costs and the anticipated proceeds from equipment salvage.
Impairment of Long-Lived Assets - In accordance with FASB ASC Topic 360, “Property, Plant and Equipment” (“ASC Topic 360”), the Company groups assets at the field level and periodically reviews the carrying value of its property and equipment to test whether current events or circumstances indicate that such carrying value may not be recoverable. If the tests indicate that the carrying value of the asset is greater than the estimated future undiscounted cash flows to be generated by such asset, then an impairment adjustment will be recognized. Such adjustment consists of the amount by which the carrying value of such asset exceeds its fair value. The Company generally measures fair value by considering sale prices for similar assets or by discounting estimated future cash flows from such asset using an appropriate discount rate. Considerable management judgment is necessary to estimate the fair value of assets, and accordingly, actual results could vary significantly from such estimates.
The Company did not incur any impairment charges during the years ended December 31, 2012 and 2011.
Deferred Financing Costs - Costs that are incurred by us in connection with the issuance of debt are capitalized and amortized to interest expense, using the effective interest method, over the expected terms of the related debt agreements.
Discount of Debt- On July 27, 2011, in order to finance the acquisition of the Adena Properties, the Company entered into a note purchase agreement (the “Note Purchase Agreement”) with Carlyle Energy Mezzanine Opportunities Fund and its affiliates (collectively “Carlyle”) as administrative agent and collateral agent. Pursuant to the Note Purchase Agreement, the Company closed on the issuance and sale of Tranche A promissory notes (the “Tranche A Notes”) in the aggregate principal amount of $18.0 million. The Tranche A Notes have been recorded net of a discount of $450,000, which is being amortized over the life of the loan. Concurrently with the issuance of the Tranche A Notes, the Company issued to the holders of the Tranche A Notes Tranche B promissory notes (“Tranche B Notes, and with the Tranche A Notes the “Senior Secured Notes”) in the aggregate principal amount of $2.5 million. The Tranche B Notes have been recorded net of a discount of $2.5 million, which is being amortized over the life of the loan. For the years ended December 31, 2012 and 2011, the Company recorded $590,000 and $246,000 of interest expense related to the amortization of the discount on its Senior Secured Notes, respectively.
Exploration Expense – The Company accounts for exploration and development activities utilizing the successful efforts method of accounting. Exploration costs, including personnel costs, certain geological and geophysical expenses and delay rentals for oil and gas leases are charged to expense as incurred. Drilling costs are initially capitalized, but charged to expense if and when the well is determined not to have found proved reserves in commercial quantities. The application of the successful efforts method of accounting requires managerial judgment to determine that proper classification of wells designated as developmental or exploratory is made to determine the proper accounting treatment of the costs incurred. The results from a drilling operation can take considerable time to analyze and the determination that commercial reserves have been discovered requires both judgment and industry experience. Wells may be completed that are assumed to be productive but actually deliver oil and gas in quantities insufficient to be economic. This may result in the abandonment of the wells at a later date. Wells are drilled that have targeted geologic structures that are both developmental and exploratory in nature and an allocation of costs is required to properly account for the results. The evaluation of oil and leasehold acquisition costs requires managerial judgment to estimate the fair value of these costs with reference to drilling activity in a given area.
Asset Retirement Obligations – The Company follows FASB ASC Topic 410, “Asset Retirement and Environmental Obligations” (“ASC Topic 410”), to account for its future asset abandonment costs. Estimated future costs associated with the plugging and abandonment of its oil and gas properties are discounted to present values using a risk-adjusted rate over the estimated economic life of the assets. Such costs are capitalized as part of the cost of the related asset and amortized over the related asset’s estimated useful life. The associated liability is classified as a long-term liability and is adjusted when circumstances change and for the accretion of expense which is recorded as a component of depreciation, depletion and amortization. The Company recognizes an estimate of the liability associated with the abandonment of oil and gas properties at the time the well is completed. The Company estimated its asset retirement obligation liabilities for these wells based on estimated costs to plug and abandon the wells, the estimated life of the wells and its respective ownership percentage in the wells.
Share-Based Compensation - At December 31, 2012, the Company had a stock-based employee compensation plan that includes stock options issued to employees and non-employee directors as more fully described in Note 11. The Company records expense associated with the fair value of stock-based compensation in accordance with FASB ASC Topic 718, “Compensation — Stock Compensation” (“ASC Topic 718”). The Company uses the Black-Scholes option valuation model to determine the fair value of awards and calculate the required disclosures.
The Company recorded compensation expense associated with all unvested stock options totaling $150,000 and $257,000 for the years ended December 31, 2012 and 2011, respectively.
Comprehensive Income (Loss) – The Company accounts for comprehensive income (loss) in accordance with FASB ASC Topic 220, “Comprehensive Income” (“ASC Topic 220”), which established standards for the reporting and presentation of comprehensive income in its consolidated financial statements. For the years ended December 31, 2012 and 2011, comprehensive income (loss) is equal to net income (loss) as reported in the Company’s consolidated statements of operations.
Derivative Financial Instruments - To mitigate a portion of the exposure to potentially adverse market changes in oil prices and the associated impact on cash flows, the Company has entered into an oil swap contract.
Off-Balance Sheet Arrangements – The Company has not participated in transactions that generate relationships with unconsolidated entities or financial partnerships, such as entities often referred to as structured finance or special purpose entities (“SPEs”), or SPEs which would have been established for the purpose of facilitating off-balance sheet arrangements or for other contractually narrow or limited purposes.
Concentration of Credit Risk- Revenues from customers which represented 10% or more of the Company’s sales for the years ended December 31, 2012 and 2011 were as follows:
| For the years ended | ||||||||
| December 31, | ||||||||
| Customer | 2012 | 2011 | ||||||
| A | 7.5 | % | 26.6 | % | ||||
| B | 91.3 | % | 66.5 | % | ||||
| 98.8 | % | 93.1 | % | |||||
Recent Accounting Pronouncements
In May 2011, the FASB issued ASC Update 2011-04, “Fair Value Measurement” (“ASC Update 2011-04”) that clarifies the application of fair value measurement and disclosure requirements and changes particular principles or requirements for measuring fair value. ASC Update 2011-04 is effective for annual periods beginning after December 15, 2011. The Company adopted ASC Update 2011-04 on January 1, 2012. Adoption of this update did not have a material impact on the Company’s fair value disclosures.
In June 2011, the FASB issued ASC Update 2011-05, “Comprehensive Income” (“ASC Update 2011-05”) that provides that an entity that reports items of other comprehensive income has the option to present the components of net income and comprehensive income in either one continuous financial statement or two consecutive financial statements. ASC Update 2011-05 is effective for annual periods beginning after December 15, 2011. The Company adopted ASC Update 2011-04 on January 1, 2012. Adoption of this update did not have a material impact on the Company’s financial statements.
The Company has reviewed all other recent accounting pronouncements and determined that they will have no impact on the Company’s financial statements.
Note 3—Farmout Agreement
On July 23, 2010, the Company entered into a Farmout Agreement with Atlas, a wholly-owned subsidiary of Atlas Energy, Inc, relating to natural gas drilling within an area of mutual interest in Phillips and Sedgwick counties, Colorado and Perkins, Chase and Dundy counties, Nebraska (the “AMI”).
Under the terms of the Farmout Agreement, Atlas agreed to drill six initial wells identified in the Farmout Agreement (the “Initial Wells”) and to complete certain initial projects, including 3D seismic shoots, upgrades of sales meter equipment, the change-out of compressors, and the upgrade of a dehydrator at the Company’s facility. The Company assigned to Atlas all of its title and interest in the defined areas around the planned wellbores (the “Drilling Units”) for the Initial Wells.
The Farmout Agreement also provides for Atlas, at its discretion, to drill additional wells in the AMI in accordance with work plans (each a “Work Plan”) approved by Atlas under the Farmout Agreement. The initial Work Plan approved by Atlas covering provided for Atlas to drill 60 additional wells. For each six month period after April 30, 2011, Atlas was required to submit a proposal to the Company setting forth the numbers of wells that it proposed to drill (the “Drilling Proposal”) and the Company was required to provide a Work Plan to be approved by Atlas outlining the development plan for the wells set forth in the Drilling Proposal. In the event that Atlas determined not to drill at least 60 wells in the course of any six month period, the Company had the right, during such six month period, to drill for its own account that number of wells equal to the difference between 60 wells and the number of wells agreed to be drilled by Atlas. Upon payment of a well-site fee, delivery of an executed authorization for expenditure (“AFE”) for such well by Atlas, and completion of drilling the applicable well, the Company assigned all of its rights, title and interest in the Drilling Units established for such well. The Farmout Agreement also provides for certain rights of the Company and Atlas with respect to the drilling of “deep wells” and for the payment by Atlas of drilling and future 3D seismic costs.
Through the first quarter of 2011, Atlas had funded and drilled an additional 40 wells pursuant to the initial Work Plan. On June 3, 2011, Atlas submitted its Drilling Proposal for the six month period beginning May 1, 2011 in which it proposed to drill 135 wells. We submitted a Work Plan, which Atlas approved. Drilling commenced on August 15, 2011. As of December 31, 2011, an additional 117 wells had been funded and drilled pursuant to the Work Plan, for a total of 163 wells.
In 2012, Atlas funded and the Company drilled an additional 51 wells, bringing the total drilled under the Farmout Agreement to 214. The Company believes that Atlas was contractually obligated to drill and fund at least 55 additional wells in 2012 under the terms of the Farmout Agreement. The Company and Atlas are currently in dispute over this matter. The Company and Atlas have participated in non-binding mediation and negotiations continue, although a final resolution has not been reached.
Restricted cash of $0.25 million and $18.6 million at December 31, 2012 and 2011, respectively, consists of cash received from Atlas for drilling activities in connection with oil and gas properties subject to the Farmout Agreement. The accounts payable balances at December 31, 2012 and 2011 contain drilling costs related to the Farmout Agreement of $97,000 and $5.6 million, respectively. Advances from Atlas of $.1 million and $14.8 million at December 31, 2012 and 2011, respectively, include cash received from Atlas for drilling activities in connection with oil and gas properties subject to the Farmout Agreement.
In consideration for the agreements made under the Farmout Agreement, Atlas paid the Company $1.0 million upon execution of the Farmout Agreement in 2010. In addition, Atlas agreed to pay the Company a $60,000 well-site fee for each well drilled by Atlas in the AMI, including the Initial Wells. As of December 31, 2012, the Company had received $12.8 million of well site fees for the 214 wells drilled through December 31, 2012. In connection with the well site fees received from Atlas, the Company recognized $3.0 million and $4.3 million of gain on sale of oil and gas properties for the years ending December 31, 2012 and 2011, respectively.
The Company’s average overriding royalty interest on the 214 wells drilled is 5.75%.
On August 11, 2010, in connection with the Farmout Agreement and ongoing investment advisory services, the Company entered into an advisory fee agreement with a third party, whereby the Company agreed to pay $10,000 per well for the first 220 wells that are funded and drilled by Atlas under the Farmout Agreement discussed above, up to a maximum fee of $2.2 million. As of December 31, 2012, Atlas had funded and drilled 214 wells and the investment advisory service fees were $2.1 million.
Note 4 —Acquisitions
Marks Butte Acquisition
On June 6, 2011, the Company acquired from Diamond Operating all of its interests in the Marks Butte area of Sedgwick County, Colorado. The purchase price was $98,500 in cash, and included title and interest in all oil and gas leases, all easements, rights-of –way, a 100% working interest in two shut-in wells, 6.15 miles of pipeline, and a compressor station with a tap into the Trailblazer Pipeline. The Company primarily acquired the assets in order to utilize the tap for the planned drilling in the East Marks Butte area as part of the Farmout Agreement.
The purchase price allocation is as follows (in thousands):
| Proved properties | $ | 38 | ||
| Unproved leaseholds | 4 | |||
| Gathering and other property and equipment | 86 | |||
| Less: Asset retirement obligation assumed | (29 | ) | ||
| Total net purchase price | $ | 99 |
Adena Field Acquisition
On July 27, 2011, the Company completed the purchase of 80% of the Adena Properties. The acquisition consists of an 80% working interest in 18,760 gross acres in Morgan County, Colorado, with a cash purchase price of $15.22 million, net of liabilities assumed and subject to adjustments for production after the effective date and other matters. The effective date of the Adena Properties acquisition was May 1, 2011. The acquisition was financed by Carlyle (see Note 9). On December 8, 2011, the Company acquired the remaining 20% working interest in the Adena Properties for a cash purchase price of $1.6 million, net of liabilities assumed and subject to post-closing adjustments as set forth in the agreement. The acquisition was effective July 1, 2011. The Company became the operator of the Adena Properties. The Company has entered into an agreement with a strategic partner who provided due diligence services in connection with the acquisition of the Adena Properties. In addition, our strategic partner will provide future geological, engineering, and management consulting services associated with the operations of this project. As compensation for the due diligence services performed for the Company, our partner earned 30% of our working interest after pay-out of all costs, including financing costs. In connection with the consulting arrangement, our partner will earn monthly consulting fees as future services are performed based on the production from the Adena Properties. In connection with the transfer of the 30% working interest called for under this agreement, the Company recorded a $1.5 million charge and reduced the value assigned to the property for the due diligence services rendered during 2011.
The purchase price allocations for the Adena Properties, are as follows (in thousands):
| July 2011 Acquisition | December 2011 Acquisition | |||||||
| Proved properties | $ | 15,635 | $ | 1,677 | ||||
| Unproved leaseholds | 292 | 31 | ||||||
| Asset retirement obligation | (557 | ) | (139 | ) | ||||
| Liabilities assumed | (148 | ) | - | |||||
| Total cash | $ | 15,222 | $ | 1,569 | ||||
The Adena Properties acquisitions qualified as business combinations and, as such, the Company estimated the fair value of the assets acquired as of the acquisition dates, July 27, 2011 and December 6, 2011. To estimate the fair values of the properties as of the acquisition dates, the Company used a net asset value approach. The Company utilized a discounted cash flow model that took into account the following inputs to arrive at estimates of future net cash flows:
To estimate the fair value of proved properties, the Company discounted the future net cash flows using a market-based rate that the Company determined appropriate at the acquisition date for the various proved reserve categories. To compensate for the inherent risk of estimating and valuing unproved properties, the Company reduced the discounted future net cash flows of the unproved properties by additional risk-weighting factors.
The revenue and operating expenses from the Adena Properties that are included in the Company’s statement of operations for the year ended December 31, 2011 are as follows:
| December 31, 2011 | ||||
| (in thousands) | ||||
| Oil and gas sales | $ | 1,033 | ||
| Operating expenses | (393 | ) | ||
The revenue and operating expenses of the combined entity had the acquisition date of the Adena Properties been January 1, 2011 are as follows:
| Unaudited Proforma | ||||
| December 31, 2011 | ||||
| (in thousands) | ||||
| Revenue | $ | 2,846 | ||
| Operating expenses | (1,413 | ) | ||
| Revenue in excess of operating expenses | $ | 1,433 | ||
Note 5 - Gathering and Other Property and Equipment
Gathering and other property and equipment consists of the following:
| Useful Lives | December 31, 2012 | December 31, 2011 | ||||||||
| (in thousands) | (in thousands) | |||||||||
| Compressor sites, pipelines and interconnect | 10-30 years | $ | 2,645 | $ | 2,477 | |||||
| Equipment | 5 years | 16 | 16 | |||||||
| Computer equipment | 3 years | 276 | 266 | |||||||
| Office furniture and equipment and related assets | 5-7 years | 159 | 158 | |||||||
| Automobiles | 3 years | 348 | 281 | |||||||
| 3,444 | 3,198 | |||||||||
| Less accumulated depreciation and amortization | (1,182 | ) | (1,078 | ) | ||||||
| Total | $ | 2,262 | $ | 2,120 | ||||||
Note 6 - Asset Retirement Obligations
The Company recognizes an estimated liability for future costs associated with the abandonment of its oil and gas properties. A liability for the fair value of an asset retirement obligation and corresponding increase to the carrying value of the related long-lived asset are recorded at the time a well is completed or acquired. The increase in carrying value is included in proved oil and gas properties in the accompanying consolidated balance sheets. The Company depletes the amount added to proved oil and gas property costs and recognizes expense in connection with the accretion of the discounted liability over the remaining estimated economic lives of the respective oil and gas properties. Cash paid to settle asset retirement obligations is included in the operating section of the Company’s accompanying consolidated statements of cash flows.
The Company’s estimated asset retirement obligation liability is based on historical experience in abandoning wells, estimated economic lives, estimates as to the cost to abandon the wells in the future, and federal and state regulatory requirements. The liability is discounted using the credit-adjusted risk-free rate estimated at the time the liability is incurred or revised. Revisions to the liability could occur due to changes in estimated abandonment costs or well economic lives, or if federal or state regulators enact new requirements regarding the abandonment of wells.
The following table details all changes to the Company’s estimated asset retirement obligation liabilities during the years ended December 31, 2012 and 2011:
| For the | ||||||||
| Year Ended | ||||||||
| December 31, | ||||||||
| 2012 | 2011 | |||||||
| (in thousands) | ||||||||
| Asset retirement obligations, beginning of period | $ | 1,034 | $ | 241 | ||||
| Liabilities incurred | 9 | 725 | ||||||
| Liabilities settled | (8 | ) | — | |||||
| Sale of assets | — | — | ||||||
| Accretion expense | 157 | 68 | ||||||
| Revision to estimated cash flows | — | — | ||||||
| Asset retirement obligations, end of period | $ | 1,192 | $ | 1,034 | ||||
Note 7 - Income Taxes
Income tax expense (benefit) for each of the years ended December 31, 2012 and 2011 are as follows:
| (in thousands) | 2012 | 2011 | ||||||
| Current: | ||||||||
| Federal | $ | — | $ | — | ||||
| State & Local | — | 54 | ||||||
| Total current | — | 54 | ||||||
| Deferred: | ||||||||
| Federal | — | — | ||||||
| State & Local | — | — | ||||||
| Total deferred | — | — | ||||||
| Total income tax expense | $ | — | $ | 54 | ||||
Total income tax expense (benefit) differed from the amounts computed by applying the federal statutory income tax rate of 35% to earnings (loss) before income taxes as a result of the following items for the years ended December 31, 2012 and 2011:
| (in thousands) | 2012 | 2011 | ||||||
| Statutory income tax benefit | $ | (1,067 | ) | $ | (819 | ) | ||
| State income tax expense, net of federal income tax expense (benefit) | (39 | ) | (16 | ) | ||||
| Other permanent items | 609 | 735 | ||||||
| Change in valuation allowance | 497 | 154 | ||||||
| Income tax expense | $ | — | $ | 54 | ||||
Deferred income tax assets and liabilities are recognized for the future tax consequences of temporary differences. Temporary differences arise when revenues and expenses for financial reporting are recognized for tax purposes in a different period. The Company has recognized, before the valuation allowance, a net deferred tax asset. ASC Topic 740 requires that a valuation allowance be recorded against deferred tax assets unless it is more likely than not that the deferred tax asset will be utilized. As a result of this analysis, the Company has recorded a full valuation allowance against its net deferred tax asset. The Company will continue to evaluate the need to record valuation allowances against deferred tax assets and will make adjustments in accordance with the accounting standard.
The tax effects of temporary differences that give rise to significant portions of the deferred tax assets and liabilities at December 31, 2012 and 2011 are as follows:
| (in thousands) | 2012 | 2011 | ||||||
| Deferred tax assets: | ||||||||
| Oil and gas properties | $ | 1,722 | $ | 1,625 | ||||
| Asset retirement obligation | 453 | 393 | ||||||
| Other | 323 | 283 | ||||||
| Net operating loss carryforwards | 14,799 | 13,140 | ||||||
| 17,297 | 15,441 | |||||||
| Valuation allowance | (14,521 | ) | (14,023 | ) | ||||
| Net deferred tax asset | $ | 2,776 | $ | 1,418 | ||||
| Deferred tax liabilities: | ||||||||
| Property and equipment | $ | (2,815 | ) | $ | (1,340 | ) | ||
| Amortization of debt discount | 39 | (78 | ) | |||||
| Deferred tax liability | (2,776 | ) | (1,418 | ) | ||||
| Net deferred tax asset (liability) | $ | — | $ | — | ||||
The Company may from time to time be assessed interest or penalties by major tax jurisdictions, although there have been no such assessments historically. In the event the Company receives an assessment for interest and/or penalties, such an assessment would be classified in the financial statements as income tax expense.
At December 31, 2012, the Company has net operating loss carryforwards for U.S. federal income tax purposes of approximately $40.4 million. These net operating loss carryforwards, if not utilized to reduce taxable income in future periods, will expire in various amounts beginning in 2028. This net operating loss carryforward may be subject to U.S. Internal Revenue Code Section 382 limitations.
The Company has recorded a valuation allowance of $14.6 million and $14.0 million as of December 31, 2012 and 2011, respectively, against its net deferred tax asset.
The uncertainty provisions of ASC Topic 740 require the Company to recognize the impact of a tax position in its financial statements only if the technical merits of that position indicate that the position is more likely than not of being sustained upon audit. During 2012, the Company did not record a change to the reserve for uncertain tax positions. The tax years 2007 - 2012 are open and subject to audit by the Internal Revenue Service and the State of Colorado.
The tabular reconciliation of the reserve for uncertain tax benefits for the years ended December 31, 2012 and 2011 is presented below.
| (in thousands) | 2012 | 2011 | ||||||
| Beginning balance | $ | 390 | $ | 390 | ||||
| Additions based on tax positions related to the current year | — | — | ||||||
| Additions based on tax positions of prior years | — | — | ||||||
| Reduction for tax positions of prior years | — | — | ||||||
| Settlements | — | — | ||||||
| Ending balance | $ | 390 | $ | 390 | ||||
The Company has an unrecognized benefit from net operating loss carryforwards. The deferred tax asset associated with the net operating losses was not recorded. The net operating loss carryforward was utilized in 2009. During 2013, the statute of limitations will expire on the tax years that generated the net operating loss that was deducted. The beginning balance in the table above will be fully utilized.
Note 8 - Commitments and Contingencies
Commitments
In the normal course of business operations, the Company has entered into operating leases for office space, office equipment, vehicles and compression equipment. Rental payments under these operating leases and service agreements totaled $266,000 and $246,000 for the periods ended December 31, 2012 and 2011, respectively.
Future payments, by year, under these operating leases are as follows:
| (in thousands) | ||||
| 2013 | $ | 167 | ||
| 2014 | 93 | |||
| 2015 | 36 | |||
| Thereafter | 12 | |||
| Total | $ | 308 | ||
Note 9 – Secured Notes & Debenture
Debenture
Since its original issuance in 2009, the terms of the Amended Debenture have been modified on several occasions. Currently, a total of approximately $21.35 million of principal is outstanding under the Amended Debenture. The outstanding principal bears interest at a rate of ten percent (10%) per annum and is due and payable on October 16, 2016. Interest is paid to WCOF on the outstanding principal at a rate equal to five percent (5%) per annum in shares of common stock of the Company in an amount based on a share price of $2.00 per share (the “Stock Interest”). Additional interest is payable to WCOF on the outstanding principal at a rate equal to five percent (5%) per annum in cash (the “Cash Interest”). The Stock Interest is due and payable to WCOF quarterly in arrears on the last day of each calendar quarter. The Cash Interest is due and payable to WCOF on the maturity date of the Amended Debenture, less $5,000 per well drilled under the Farmout Agreement (see Note 3), which is payable to WCOF upon the Company’s receipt of the applicable well-site fees from Atlas under the Farmout Agreement.
The Company has guaranteed payment of the Amended Debenture and pledged substantially all of its assets as collateral. If the Company fails to comply with the restrictions in the agreements governing the Amended Debenture, an event of default could occur that would permit WCOF to foreclose on substantially all of its assets. The Company and WCOF have agreed that no event of default shall occur on the Amended Debenture until written notice of default is given to the Company by WCOF and such default shall have continued for a period of 30 days after written notice is delivered to the Company.
In connection with the financing of the Adena Properties acquisition described below, WCOF agreed to subordinate the payment obligations under the Amended Debenture and related security interests to the payment obligations arising under the Adena Properties acquisition financing, pursuant to the terms and conditions of an intercreditor and subordination agreement. As further security, WCOF has also pledged to the lenders all of its shares of stock in the Company.
The Company is in compliance with all the terms, conditions and covenants of the Amended Debenture, as of December 31, 2012 and 2011.
Senior Secured Notes
On July 27, 2011, in order to finance the acquisition of the Adena Properties, the Company entered into the Note Purchase Agreement with Carlyle. Pursuant to the Note Purchase Agreement, the Company closed on the issuance and sale of the Tranche A Notes in the aggregate principal amount of $18.0 million. The Tranche A Notes mature and are due and payable on July 27, 2016. They bear interest at a stated rate of 13% per annum, of which 10% must be paid in cash, and, at the election of the Company, 3% may be paid in cash or paid in kind and capitalized into the Tranche A Notes. The Tranche A Notes have been recorded net of a discount of $450,000, which is being amortized over the life of the loan. For the years ended December 31, 2012 and 2011, respectively, amortization of the Tranche A debt discount was $90,000 and $38,000. A portion of the proceeds received from the sale of the Tranche A Notes was used for the acquisition of the Adena Properties with the balance used according to a mutually approved plan of development for the Adena Properties. The Company was required to establish a reserve account pursuant to the Note Purchase Agreement in the amount of $450,000, which is included in restricted cash (non-current) within the condensed consolidated balance sheets.
Subject to certain conditions, the Company can voluntarily prepay the Tranche A Notes. If the Company prepays the Tranche A Notes before July 31, 2014, subject to certain exceptions, the Company must pay a “make-whole” amount, equal to the present value at the time of the prepayment of the amount of interest which would have been payable on the principal balance of the Tranche A Notes through July 31, 2014.
Concurrently with the issuance of the Tranche A Notes, the Company issued to the holders of the Tranche A Notes the Tranche B Notes in the aggregate principal amount of $2.5 million with a stated interest rate of 13% per annum, all of which is paid in kind and capitalized into the Tranche B Notes. The Company may prepay the Tranche B Notes only in whole, and upon prepayment, the Company must pay a “make-whole” amount, equal to $1.2 million less the amount of paid in kind interest that has been capitalized into the Tranche B Notes as of such date. The Tranche B Notes have been recorded net of a discount of $2.5 million, which is being amortized over the life of the loan, as no proceeds were received upon issuance of the Tranche B Notes. For the years ended December 31, 2012 and 2011, respectively, amortization of the Tranche B debt discount was $500,000 and $208,000. The Tranche B Notes are due and payable on the earlier July 27, 2016, or the repayment of the Tranche A Notes.
The Company incurred deferred financing costs totaling $1.3 million in connection with the issuance of the Senior Secured Notes. As additional consideration for the issuance of the Senior Secured Notes, the Company conveyed to the holders of the Senior Secured Notes overriding royalty interests equal to 3% of 8/8ths in the Adena Properties and agreed to convey overriding royalty interests in any future oil and gas properties acquired by the Company, subject to certain permissible acquisitions, during the term of the Note Purchase Agreement. The Company has estimated the value of the overriding royalty interests to be $2.4 million at the date of the financing and has recorded additional deferred financing costs associated with its Senior Secured Notes related to these interests. The Company’s deferred financing costs will be amortized to interest expense over the term of the Note Purchase Agreement. If future overriding royalty interests in oil and gas properties acquired by the Company are conveyed to Carlyle under the terms of the Note Purchase Agreement, additional deferred financing costs will be recorded and amortized as an adjustment to the yield on the Senior Secured Notes over the remaining period of the Note Purchase Agreement. Depending on the nature of any future acquisitions made by the Company, the value of the applicable additional overriding royalty interests conveyed to Carlyle may be material to the Company’s financial position or results of operations.
The Senior Secured Notes are collateralized by substantially all of the assets of the Company and its subsidiaries. The Senior Secured Notes are subject to customary events of default. Upon the occurrence of an event of default, as described in the Note Purchase Agreement, the payment of the principal amounts under the Senior Secured Notes may be accelerated and the interest rate applicable to the principal amounts will be increased to a stated interest rate of 16% per annum during the period the default exists. WCOF, a majority stockholder in the Company and the holder of the Amended Secured Debentures discussed above, agreed to subordinate the payment obligations under the Amended Debenture and related security interests to the payment obligations arising under the Senior Secured Notes and the security interests securing payment of the Senior Secured Notes, pursuant to the terms and conditions of an intercreditor and subordination agreement. As further security for the payment of the Senior Secured Notes, WCOF pledged to Carlyle all of its shares of stock in the Company.
The Company is subject to various financial and operational covenants under the terms of the Note Purchase Agreement. The Company was in compliance with its interest coverage ratio, leverage ratio, maximum consolidated capital expenditures, and net present value of total proved developed producing reserves to total debt covenants as of December 31, 2011. The Company was in violation of its minimum net sales volume and net present value of total proved reserves to total debt covenants as of December 31, 2011 and 2012. In addition, the Company was in violation of their financial reporting requirements for 2011 and 2012. Carlyle has waived each of these covenant violations. Interest of $477,000 and $180,000 on the Senior Secured Notes was converted to principal during 2012 and 2011, respectively.
Note 10 - Stockholders’ Equity
Common Stock
Through December 31, 2012 and 2011, respectively, cumulative activity with respect to the Company’s common stock outstanding was as follows:
| 2012 | 2011 | |||||||
| Balance, beginning of year | 17,129,296 | 16,660,965 | ||||||
| Shares issued for interest | 472,478 | 468,331 | ||||||
| Balance, end of year | 17,601,774 | 17,129,296 | ||||||
Upon emergence from bankruptcy, the Company issued warrants to purchase 1,494,298 shares of new common stock at an exercise price of $2.50 per share, on a pro-rata basis, pursuant to its reorganization plan.
Note 11 - Equity Compensation Plan
On June 3, 2009, the Board adopted the Black Raven Energy, Inc. Equity Compensation Plan (the “Equity Compensation Plan”) under which the Company may grant nonqualified stock options, stock appreciation rights, stock awards or other equity-based awards to certain of its employees, consultants, advisors and non-employee directors. The Board initially reserved 3,791,666 shares of common stock for issuance under the Equity Compensation Plan, and that number is adjusted annually to 25% of shares issued and outstanding on July 1. As of December 31, 2012, there are 4,223,264 shares of common stock authorized for issuance under the Equity Compensation Plan.
On August 18, 2011, the Company issued 100,000 options to two directors. The options have an exercise price of $2.00 per share and a total estimated fair value as of issuance of $4,500. In October 2011, the Company issued 63,000 options to employees of the Company. The options have an exercise price of $2.00 per share, a total estimated fair value as of issuance of $3,308 and vest over five years. In November and December 2011, the Company issued 4,000 options to employees of the Company. The options have an exercise price of $2.00 per share, and a total estimated fair value as of issuance of $210.
On January 31, 2012, the Company issued 3,200 options to two employees. The options have an exercise price of $2.00 per share and a total estimated fair value as of issuance of $168. The options vest over four years. On April 18, 2012, the Company issued 800 options to the same two employees. These options have an exercise price of $2.00 per share, a total estimated fair value as of issuance of $48 and vest immediately. On October 10, the Company issued 100,000 options to two directors. The options have an exercise price of $2.00 per share and a total estimated fair value as of issuance of $4,500.
The Company recorded equity compensation expense during the years ended December 31, 2012 and 2011 totaling $150,000 and $257,000, respectively.
The following table summarizes activity for options:
| For the Year Ended | For the Year Ended | |||||||||||||||
| December 31, 2012 | December 31, 2011 | |||||||||||||||
| Number of Options | Weighted Avg. Exercise Price | Number of Options | Weighted Avg. Exercise Price | |||||||||||||
| Outstanding, beginning of year | 1,814,500 | $ | 2.00 | 1,647,500 | $ | 2.00 | ||||||||||
| Cancelled | — | $ | — | — | $ | — | ||||||||||
| Granted | 104,000 | $ | 2.00 | 167,000 | $ | 2.00 | ||||||||||
| Forfeitures | — | $ | — | — | $ | — | ||||||||||
| Exercised | — | $ | — | — | $ | — | ||||||||||
| Outstanding, end of year | 1,918,500 | $ | 2.00 | 1,814,500 | $ | 2.00 | ||||||||||
| Awards vested or expected to vest, end of year | 1,881,800 | $ | 2.00 | 1,670,583 | $ | 2.00 | ||||||||||
| Available for future grants, end of year | 2,246,741 | 2,412,764 | ||||||||||||||
The weighted average remaining contractual life for the options outstanding at December 31, 2012 and 2011 respectively is 7.09 years and 7.94 years. The fair value of each option granted is estimated on the date of grant using the Black-Scholes option pricing model. Unrecognized compensation expense totaled $46,000 and $196,000 at December 31, 2012 and December 31, 2011, respectively.
The fair value of options was measured at the date of grant. The fair values of options granted and employee stock purchase plan shares issued were estimated using the following weighted-average assumptions:
| Assumption | December 31, 2012 | December 31, 2011 | ||||||
| Risk free interest rate (%) | 0.36% - 0.40% | 0.33% - 0.47% | ||||||
| Volatility factor of the expected market price of the Company’s common stock | 52.07% – 57.53% | 51.76% – 55.72% | ||||||
| Contract life of the options (in years) | 10 | 10 | ||||||
| Expected dividend | — | — | ||||||
The Black-Scholes option valuation model was developed for use in estimating the fair value of traded options that have no vesting restrictions and are fully transferable. In addition, option valuation models incorporate highly subjective assumptions including the expected stock price volatility. The Company’s stock options have characteristics significantly different from those of traded options and, as changes in the subjective input assumptions can materially affect the fair value estimate, it is management’s opinion that the valuations as determined by the existing models are different from the value that the options would realize if traded in the market. The Company used an industry index to estimate the volatility factor of the stock.
Note 12 - Oil and Gas Activities
Costs Incurred in Oil and Gas Producing Activities
The Company has incurred the following costs, both capitalized and expensed, in respect to oil and gas property acquisition, exploration and development activities during the year ended December 31, 2012 and 2011, respectively:
| For the Years Ended December 31, | ||||||||
| (in thousands) | 2012 | 2011 | ||||||
| Acquisitions | ||||||||
| Proved | $ | 57 | $ | 13,749 | ||||
| Unproved | 103 | 383 | ||||||
| Exploration | 13 | 9 | ||||||
| Development costs | 3,951 | 1,736 | ||||||
| $ | 4,124 | $ | 15,877 | |||||
The following table sets forth certain information regarding the results of operations for oil and gas producing activities for the years ended December 31, 2012 and 2011, respectively:
| For the Years Ended December 31, | ||||||||
| (in thousands) | 2012 | 2011 | ||||||
| Revenues, net | $ | 4,023 | $ | 1,388 | ||||
| Production costs | (1,679 | ) | (762 | ) | ||||
| Exploration | (13 | ) | (9 | ) | ||||
| Depreciation, depletion and accretion | (1,287 | ) | (507 | ) | ||||
| $ | 1,044 | $ | 110 | |||||
Note 13 —Derivative Financial Instruments
To mitigate a portion of the exposure to potentially adverse market changes in oil prices and the associated impact on cash flows, the Company has entered into an oil swap contract. For the years ending December 31, 2011 & December 31, 2012, the Company has a forward contract in place through July 31, 2014 for a total of 64,000 barrels of crude oil production.
The Company’s oil derivatives are measured at fair value and are included in the accompanying condensed consolidated balance sheets as derivative assets. The fair value is an estimated exit-price that management believes provides a reasonable and consistent methodology for valuing derivative instruments. The derivative instruments utilized by the Company are not considered by management to be complex, structured, or illiquid. The oil derivative markets are highly active. The fair value of the Company’s oil commodity derivative contract was a net asset of $283,000 and $222,000 at December 31, 2012 and 2011, respectively.
Derivative Assets
(in thousands)
| Balance Sheet Classification | Dec 31, 2012 Fair Value | Dec 31, 2011 Fair Value | ||||||||
| Commodity Contracts | Current Derivative Asset | $ | 178 | $ | 30 | |||||
| Commodity Contracts | Non-current Derivative Asset | 105 | 192 | |||||||
| Derivatives not designated as hedging instruments | $ | 283 | $ | 222 | ||||||
The following table summarizes the realized gain and loss from derivative cash settlements and the unrealized gain and loss from changes in fair value of derivative contracts as presented in the accompanying statements of operations.
| For the Years Ended December 31, | ||||||||
| (in thousands) | 2012 | 2011 | ||||||
| Realized gain | ||||||||
| Oil contracts | $ | 146 | $ | 95 | ||||
| Total realized gain | $ | 146 | $ | 95 | ||||
| Unrealized gain on changes in fair value | ||||||||
| Oil contracts | $ | 61 | $ | 222 | ||||
| Total unrealized gain on changes in fair value | $ | 61 | $ | 222 | ||||
| Total unrealized and realized gain on derivative contract | $ | 207 | $ | 317 | ||||
Note 14 —Fair Value Measurements
The Company follows FASB ASC Topic 820, “Fair Value Measurement and Disclosure”, which establishes a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement. The three levels are defined as follows:
| · | Level 1: Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of financial instruments such as exchange-traded derivatives, listed securities and U.S. government treasury securities. |
| · | Level 2: Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of the assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in this category include non-exchange-traded derivatives such as over-the-counter forwards and options. |
| · | Level 3: Pricing inputs include significant inputs that are generally less observable that objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value. At each balance hseet date, the Company performs an analysis of all applicable instruments and includes in Level 3 all of those whose fair value is based on significant unobservable inputs. |
A financial instrument’s categorization within the valuation hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability. The Company reflects transfers between the three levels at the beginning of the reporting period in which the availability of observable inputs no longer justifies classification in the original level.
The following tables set forth by level within the fair value hierarchy the Company’s financial assets and financial liabilities as of December 31, 2012 and 2011 that are measured at fair value on a recurring basis.
As of December 31, 2012
| Level 1 | Level 2 | Level 3 | Total | |||||||||||||
| (in thousands) | ||||||||||||||||
| Assets | ||||||||||||||||
| Current Derivative Assets | $ | - | $ | 178 | $ | - | $ | 178 | ||||||||
| Non-current Derivative Assets | - | 105 | - | 105 | ||||||||||||
As of December 31, 2011
| Level 1 | Level 2 | Level 3 | Total | |||||||||||||
| (in thousands) | ||||||||||||||||
| Assets | ||||||||||||||||
| Current Derivative Assets | $ | - | $ | 30 | $ | - | $ | 30 | ||||||||
| Non-current Derivative Assets | - | 192 | - | 192 | ||||||||||||
The following methods and assumptions were used to estimate the fair values of the assets and liabilities in the tables above:
Derivatives - Commodity derivative instruments consist entirely of crude oil swaps. The Company’s derivatives are valued using industry-standard models, which are based on a market approach. These models consider various assumptions, including quoted forward prices for commodities, time value and volatility factors. These assumptions are observable in the marketplace throughout the full term of the contracts, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace, and are therefore designated as Level 2 within the valuation hierarchy. The discount rates used in the fair values of these instruments include a measure of either the Company’s or the counterparty’s nonperformance risk, as appropriate. The Company utilizes counterparties’ valuations to assess the reasonableness of its own valuations.
For the year ending December 31, 2012, there were no financial assets and financial liabilities that were measured at fair value on a non-recurring basis. The following table set forth by level within the fair value hierarchy the Company’s financial assets and financial liabilities as of December 31, 2011 that were measured at fair value on a non-recurring basis:
As of December 31, 2011
| Level 1 | Level 2 | Level 3 | Total | |||||||||||||
| (in thousands) | ||||||||||||||||
| Assets | ||||||||||||||||
| Oil and gas properties - proved | $ | - | $ | - | $ | 13,749 | $ | 13,749 | ||||||||
| Oil and gas properties – unproved | - | - | 383 | 383 | ||||||||||||
| Gathering and other property and equipment | - | - | 86 | 86 | ||||||||||||
| Liabilities | ||||||||||||||||
| Accrued expenses | $ | - | $ | - | $ | 148 | $ | 148 | ||||||||
| Asset retirement obligation | - | - | 725 | 725 | ||||||||||||
The following methods and assumptions were used to estimate the fair values of the assets and liabilities in the tables above:
Properties and Equipment - To estimate the fair value of proved properties, the Company discounted the future net cash flows using a market-based rate that the Company determined appropriate at the acquisition date for the various proved reserve categories. To compensate for the inherent risk of estimating and valuing unproved properties, the Company reduced the discounted future net cash flows of the unproved properties by additional risk-weighting factors. Due to the unobservable nature of the inputs, the fair values of the proved and unproved oil and gas properties are considered Level 3 fair value measurements.
The Company estimated the fair values of the property and equipment related to the Marks Butte acquisition and the Adena Field acquisitions as of the acquisition dates, using a net asset value approach (See Note 4).
Other Fair Value Disclosures
The Company’s financial instruments, including cash and cash equivalents, restricted cash, accounts receivable, accounts payable and secured debentures, are carried at cost. At December 31, 2012, the fair value of the cash and cash equivalents, restricted cash, accounts receivable and accounts payable approximates their carrying value due to the short term nature of these instruments. Due to the nature of the Amended Debenture, the Company is unable to reliably estimate its fair value at December 31, 2012. The fair value of the Company’s Senior Secured Notes approximates book value due to the recent issuance of these instruments.
Note 15 —Subsequent Events
Derivatives – On April 1, 2013 the Company entered into a forward contract effective April 1, 2013 through July 31, 2014 for a total of 16, 000 barrels of oil. Also on April 1, 2013 the Company entered into a forward contract effective August 1, 2014 through December 31, 2014 for a total of 15,000 barrels of oil.
Merger – On July 23, 2013, EnerJex Resources, Inc., a Nevada corporation (“EnerJex”), BRE Merger Sub, Inc., a Delaware corporation and a wholly owned subsidiary of EnerJex (the “Merger Sub”), and Black Raven Energy, Inc., a Nevada corporation (“BRE”), entered into an agreement and plan of merger (the “Merger Agreement”) pursuant to which BRE will be merged with and into Merger Sub and after which BRE will be a wholly owned subsidiary of EnerJex (the “Merger”). The Merger will be subject to the approval of the issuance of shares of EnerJex common stock in the Merger by holders of a majority of the shares of EnerJex common stock and Series A preferred stock, voting together as a single class, present and entitled to vote at the stockholders meeting at which the transaction will be considered.
Pursuant to the terms of the Merger Agreement, at the effective time of the Merger (the “Effective Time”): (i) each outstanding share of capital stock of BRE will be converted into the right to receive (a) a cash payment of $0.40 (subject to an aggregate cap of $600,000) or (b) 0.34791 of a share of EnerJex common stock, subject to adjustment as described in the Merger Agreement, (ii) all options under the BRE option plan shall be cancelled, and (iii) all warrants or other rights to purchase shares of capital stock of BRE will be converted into warrants to purchase EnerJex common stock. The election to receive cash in lieu of EnerJex shares is available only to unaffiliated stockholders of BRE. No fractional shares of EnerJex common stock will be issued in connection with the Merger, and holders of BRE common stock will be entitled to receive cash in lieu thereof. Following the consummation of the transactions contemplated by the Merger Agreement, the stockholders of BRE immediately prior to the Effective Time will own approximately 37% of the outstanding voting stock of EnerJex and the stockholders of EnerJex immediately prior to the Effective Time will own approximately 63% of the outstanding voting stock of EnerJex. The Merger is intended to qualify as a “reorganization” within the meaning of Section 368(a) of the Internal Revenue Code of 1986, as amended.
The Merger Agreement provides that, immediately following the Effective Time, the board of directors and executive officers of EnerJex will remain the same.
Consummation of the Merger is subject to a number of conditions, including, but not limited to (i) approval by EnerJex’s stockholders of the issuance of shares of EnerJex common stock in the Merger and the adoption and approval of the Merger Agreement and the transactions contemplated thereby by BRE’s stockholders; (ii) the effectiveness of a Form S-4 registration statement to be filed by EnerJex with the Securities and Exchange Commission (the “SEC”) to register the shares of EnerJex common stock to be issued in the Merger, which will include a proxy statement/prospectus; and (iii) other customary closing conditions.
Each of EnerJex and BRE has made customary representations, warranties and covenants in the Merger Agreement, including agreements that (i) each party will conduct its business in the ordinary course consistent with past practice during the interim period between execution of the Merger Agreement and consummation of the Merger; (ii) each party will not take certain actions during such period; (iii) BRE will receive the written consent of a majority of its stockholders in favor of the transaction within 24 hours after execution of the Merger Agreement; and (iv) EnerJex will convene and hold a meeting of its stockholders for the purpose of considering the approval of the issuance of shares of EnerJex common stock in the Merger. BRE also has agreed not to solicit proposals relating to alternative business combination transactions and not to enter into discussions or any agreement concerning any alternative business combination transaction, subject to customary fiduciary exceptions.
On July 24, 2013, holders of a majority of the voting stock of BRE delivered to EnerJex their consent to the transactions contemplated by the Merger Agreement.
The Merger Agreement contains termination rights in favor of each of BRE and EnerJex in certain circumstances. If the Merger Agreement is terminated due to certain triggering events specified in the Merger Agreement, EnerJex will be required to pay BRE a termination fee of up to $1.0 million or BRE will be required to pay EnerJex a termination fee of up to $2.0 million.
BLACK RAVEN ENERGY INC.
Balance Sheet
| June 30, 2013 | ||||
| Assets | ||||
| Current: | ||||
| Cash | $ | 1,858,531 | ||
| Cash, restricted | 678,983 | |||
| Oil and gas revenue receivable | 451,752 | |||
| Other receivables | 342,296 | |||
| Derivative asset, current | 159,930 | |||
| Inventory | 26,801 | |||
| Prepaid expenses | 182,063 | |||
| Total current assets | 3,700,356 | |||
| Property and equipment at cost: | ||||
| Proved properties | 7,788,326 | |||
| Unproved leasehold costs | 135,961 | |||
| Gathering system | 3,020,202 | |||
| Lease and well equipment | 17,274,367 | |||
| Asset retirement obligations | 858,583 | |||
| Computer and office equipment | 278,178 | |||
| Furniture and fixtures | 141,083 | |||
| Vehicles | 347,637 | |||
| Other | 37,125 | |||
| Total property and equipment | 29,881,462 | |||
| Less accumulated depreciation, depletion and amortization | (4,599,139 | ) | ||
| Net property and equipment | 25,282,323 | |||
| Other Assets: | ||||
| Deposits | 727,606 | |||
| Derivative asset, long-term | 51,760 | |||
| Deferred Debt Issuance Costs, net | 2,264,261 | |||
| Investment in PRB Gathering | 100 | |||
| Total other assets | 3,043,727 | |||
| $ | 32,026,406 | |||
| F-25 |
BLACK RAVEN ENERGY INC.
Balance Sheet
| June 30, 2013 | ||||
| Liabilities | ||||
| Current liabilities: | ||||
| Accounts payable | $ | 1,023,020 | ||
| Taxes payable | 354,608 | |||
| Revenue payable | 246,944 | |||
| Interest payable | 2,183,159 | |||
| Interest payable, stock | 552,977 | |||
| Other accrued | 578,493 | |||
| Advances from Atlas | 224,312 | |||
| Total current liabilities | 5,163,513 | |||
| West Coast Capital Long-term debt | 23,945,618 | |||
| Carlyle Long-term note payable | 16,902,080 | |||
| Vehicle Long-term note payable | 65,446 | |||
| Total long-term liabilities | 40,913,144 | |||
| Other liabilities: | ||||
| Asset retirement obligation | 1,213,135 | |||
| Total liabilities | 47,289,792 | |||
| Shareholders' deficit | ||||
| Common Stock, $.001 par value, 150,000,000 shares authorized and 17,725,134 issued | 17,725 | |||
| Additional paid in capital | 32,294,055 | |||
| Accumulated deficit | (47,575,166 | ) | ||
| Total shareholders’ deficit | (15,263,386 | ) | ||
| $ | 32,026,401 | |||
BLACK RAVEN ENERGY INC.
Statement of Operations and Deficit
| Six months ended | ||||
| June 30, 2013 | ||||
| Revenues: | ||||
| Oil sales | $ | 1,932,138 | ||
| Gas sales | 300,439 | |||
| Other sales | 50,416 | |||
| Geological Services | 20,000 | |||
| Hedging income/(loss) | 350 | |||
| Total revenues | 2,303,343 | |||
| Expenses: | ||||
| Project operating expenses | 836,476 | |||
| Production taxes | 179,265 | |||
| Depreciation, depletion and accretion | 934,516 | |||
| General and administrative | 687,028 | |||
| Total expenses | 2,637,285 | |||
| Loss from operations | (333,942 | ) | ||
| Other income and (expenses): | ||||
| Interest and other income | (18,002 | ) | ||
| Interest expense | (2,806,409 | ) | ||
| Total other income and (expenses) | (2,824,411 | ) | ||
| Net loss before income tax expense | (3,158,353 | ) | ||
| Provision for income taxes (benefit) | — | |||
| Net loss for the period | (3,158,353 | ) | ||
| Deficit, beginning of period | (44,416,813 | ) | ||
| Deficit, end of period | $ | (47,575,166 | ) | |
| F-27 |
BLACK RAVEN ENERGY INC.
Statement of Operations and Deficit
| Month ended | ||||
| June 30, 2013 | ||||
| Revenues: | ||||
| Oil sales | $ | 301,308 | ||
| Gas sales | 53,457 | |||
| Other sales | 6,835 | |||
| Hedging income/(loss) | (30,787 | ) | ||
| Total revenues | 330,813 | |||
| Expenses: | ||||
| Project operating expenses | 236,026 | |||
| Production taxes | 28,193 | |||
| Depreciation, depletion and accretion | 166,056 | |||
| General and administrative | 153,589 | |||
| Total expenses | 583,864 | |||
| Loss from operations | (253,051 | ) | ||
| Other income and (expenses): | ||||
| Interest and other income | (18,964 | ) | ||
| Interest expense | (626,645 | ) | ||
| Total other income and (expenses) | (645,609 | ) | ||
| Net loss before income tax expense | (898,660 | ) | ||
| Provision for income taxes (benefit) | — | |||
| Net loss for the period | (898,660 | ) | ||
| Deficit, beginning of period | (46,676,506 | ) | ||
| Deficit, end of period | $ | (47,575,166 | ) | |
BLACK RAVEN ENERGY INC.
Statement of Operations and Deficit
| Quarter ended | ||||
| June 30, 2013 | ||||
| Revenues: | ||||
| Oil sales | $ | 921,455 | ||
| Gas sales | 153,586 | |||
| Other sales | 24,636 | |||
| Hedging income/(loss) | (16,676 | ) | ||
| Total revenues | 1,083,001 | |||
| Expenses: | ||||
| Project operating expenses | 498,969 | |||
| Production taxes | 85,682 | |||
| Depreciation, depletion and accretion | 550,640 | |||
| General and administrative | 334,237 | |||
| Total expenses | 1,469,528 | |||
| Loss from operations | (386,527 | ) | ||
| Other income and (expenses): | ||||
| Interest and other income | (18,542 | ) | ||
| Interest expense | (1,523,219 | ) | ||
| Total other income and (expenses) | (1,541,761 | ) | ||
| Net loss before income tax expense | (1,928,288 | ) | ||
| Provision for income taxes (benefit) | — | |||
| Net loss for the period | (1,928,288 | ) | ||
| Deficit, beginning of period | (45,646,878 | ) | ||
| Deficit, end of period | $ | (47,575,166 | ) | |
BLACK RAVEN ENERGY INC.
Statement of Cash Flows
| Six months ended | ||||
| June 30, 2013 | ||||
| Cash Flows from Operating Activities: | ||||
| Net loss | $ | (3,158,353 | ) | |
| Adjustments to reconcile net loss to net cash Used in operating activities: | ||||
| Depreciation, depletion and accretion | 934,516 | |||
| Debt issuance cost amortization | 367,177 | |||
| Debt discount amortization | 294,999 | |||
| Share-based compensation expense | 9,598 | |||
| Stock issued for interest | 246,434 | |||
| Debt issued for interest | 238,653 | |||
| Loss on sale of assets | 1,290 | |||
| Unrealized gain on swap contracts | 151,543 | |||
| Changes in operating assets and liabilities: | ||||
| Restricted cash from Atlas | 20,320 | |||
| Advances from Atlas | 74,321 | |||
| Accounts receivable | (63,533 | ) | ||
| Prepaid expenses | (37,698 | ) | ||
| Other non-current assets | (95,312 | ) | ||
| Accounts payable | (372,683 | ) | ||
| Asset Retirement Obligation | (201,119 | ) | ||
| Accrued expenses and other current liabilities | 1,826,161 | |||
| Net cash provided by operating activities | 236,314 | |||
| Cash Flows from Investing Activities: | ||||
| Additions to property and equipment | (2,688,320 | ) | ||
| Restricted cash related to Carlyle long term debt | (137 | ) | ||
| Proceeds from sale of assets | 12,000 | |||
| Net cash used in investing activities | (2,676,457 | ) | ||
| Cash Flows from Financing Activities – | ||||
| Proceeds from senior secured debentures | 2,598,000 | |||
| Repayment of debt | (18,192 | ) | ||
| Net cash provided by financing activities | 2,579,808 | |||
| Decrease in cash and cash equivalents | 139,665 | |||
| Cash and cash equivalents, beginning of period | 1,718,866 | |||
| Cash and cash equivalents, end of period | $ | 1,858,531 | ||
| F-30 |
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Shareholders of
EnerJex Resources, Inc.
We have audited the accompanying consolidated balance sheets of EnerJex Resources, Inc. and Subsidiaries as of December 31, 2012, and 2011, and the related consolidated statements of operations, stockholders’ equity, and cash flows for the years then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these financial statements based on our audits.
We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the auditaudits to obtain reasonable assurance about whether the financial statements are free of material misstatements.misstatement. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. Our audit included consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit also includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includesstatements, assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the consolidated financial position of EnerJex Resources, Inc. and Subsidiaries as of MarchDecember 31, 20092012, and 20082011, and the consolidated results of its consolidated operations, stockholders’ equity, and cash flows for each of the years in the two–year periodthen ended March 31, 2009 in conformity with accounting principles generally accepted in the United States of America.
/s/ Weaver, Martin & Samyn
Weaver, Martin & Samyn, LLC
Kansas City, Missouri
April 10, 2013
| F-31 |
EnerJex Resources, Inc. and Subsidiaries
Consolidated Balance Sheets
| December 31, | ||||||||
| 2012 | 2011 | |||||||
| Assets | ||||||||
| Current Assets: | ||||||||
| Cash | $ | 767,494 | $ | 2,770,440 | ||||
| Accounts receivable | 1,221,962 | 1,454,405 | ||||||
| Marketable securities | 1,018,573 | 1,018,573 | ||||||
| Deposits and prepaid expenses | 374,592 | 114,436 | ||||||
| Total current assets | 3,382,621 | 5,357,854 | ||||||
| Fixed assets | 629,816 | 529,371 | ||||||
| Accumulated depreciation | (319,939 | ) | (232,508 | ) | ||||
| Total fixed assets | 309,877 | 296,863 | ||||||
| Other Assets | ||||||||
| Oil properties using full-cost accounting: | ||||||||
| Properties not subject to amortization | 7,830,828 | 7,922,734 | ||||||
| Properties subject to amortization | 25,372,070 | 17,837,766 | ||||||
| Total oil properties using full-cost accounting | 33,202,898 | 25,760,500 | ||||||
| Total assets | $ | 36,895,396 | $ | 31,415,217 | ||||
| Liabilities and Stockholders' Equity (Deficit) | ||||||||
| Current liabilities: | ||||||||
| Accounts payable | $ | 2,384,090 | $ | 2,355,692 | ||||
| Accrued liabilities | 590,205 | 123,789 | ||||||
| Derivative liability | 757,181 | 959,114 | ||||||
| Note Payable | 825,000 | - | ||||||
| Long-term debt, current | - | 7,000 | ||||||
| Total current liabilities | 4,556,476 | 3,445,595 | ||||||
| Non-Current Liabilities | ||||||||
| Asset retirement obligation | 1,336,151 | 908,790 | ||||||
| Derivative liability | 1,043,114 | 1,768,220 | ||||||
| Long-term debt | 8,500,000 | 3,826,484 | ||||||
| Total non-current liabilities | 10,879,265 | 6,503,494 | ||||||
| Total liabilities | 15,435,741 | 9,949,089 | ||||||
| Commitments and Contingencies | ||||||||
| Stockholders' Equity (Deficit): | ||||||||
| Preferred stock, $0.001 par value, 10,000,000 shares authorized, 4,779,460 shares issued and outstanding | 4,780 | 4,780 | ||||||
| Common stock, $0.001 par value, 100,000,000 shares authorized; shares issued and outstanding - 73,586,529 at December 31, 2012, and 73,411,279 at December 31, 2011 | 73,587 | 73,412 | ||||||
| Treasury stock, 5,570,000 shares at December 31, 2012, and 3,750,000 shares at December 31,2011 | (2,551,000 | ) | (1,500,000 | ) | ||||
| Equity based compensation unearned | (153,876 | ) | (230,813 | ) | ||||
| Accumulated other comprehensive income | (552,589 | ) | (552,589 | ) | ||||
| Paid in capital | 45,352,096 | 43,556,486 | ||||||
| Retained (deficit) | (20,713,343 | ) | (20,450,876 | ) | ||||
| Total stockholders’ equity EnerJex Resources Inc. | 21,459,655 | 20,900,400 | ||||||
| Non-controlling interest in subsidiary | - | 565,728 | ||||||
| Total stockholders' equity (deficit) | 21,459,655 | 21,466,128 | ||||||
| Total liabilities and stockholders' equity (deficit) | $ | 36,895,396 | $ | 31,415,217 | ||||
See Notes to Consolidated Financial Statements.
EnerJex Resources, Inc. and Subsidiaries
Consolidated Statements of Operations
| Year Ended December 31, | ||||||||
| 2012 | 2011 | |||||||
| Oil revenues | $ | 8,496,519 | $ | 6,516,411 | ||||
| Expenses: | ||||||||
| Direct operating costs | 3,102,321 | 3,671,228 | ||||||
| Depreciation, depletion and amortization | 1,633,467 | 1,128,712 | ||||||
| Professional fees | 1,483,720 | 1,453,386 | ||||||
| Salaries | 601,533 | 502,924 | ||||||
| Administrative expense | 808,836 | 960,744 | ||||||
| Total expenses | 7,629,877 | 7,716,994 | ||||||
| Income (loss) from operations | 866,642 | (1,200,583 | ) | |||||
| Other income (expense): | ||||||||
| Interest expense | (302,357 | ) | (463,021 | ) | ||||
| Gain (loss) on derivatives | 55,708 | (409,399 | ) | |||||
| Other income (expense) | 121,127 | 55,741 | ||||||
| Total other income (expense) | (125,522 | ) | (816,679 | ) | ||||
| Income before provision for income taxes | 741,120 | (2,017,262 | ) | |||||
| Provision for income taxes | - | - | ||||||
| Net income (loss) | $ | 741,120 | $ | (2,017,262 | ) | |||
| Net income (loss) attributed to EnerJex Resources Inc. | $ | 345,992 | $ | (2,038,622 | ) | |||
| Net income (loss) attributed to non-controlling interest in subsidiary | 395,128 | 21,360 | ||||||
| Net income (loss) | $ | 741,120 | $ | (2,017,262 | ) | |||
| Net income (loss) attributed to EnerJex Resources Inc. | 345,992 | (2,038,622 | ) | |||||
| Preferred dividends | (608,459 | ) | (56,263 | ) | ||||
| Net (loss) attributed to EnerJex Resources Inc. common stockholders | (262,467 | ) | (2,094,885 | ) | ||||
| Net Income (loss) per share- basic and diluted | $ | 0.00- | $ | (.03 | ) | |||
| Weighted average shares outstanding | 69,714,758 | 69,029,617 | ||||||
See Notes to Consolidated Financial Statements.
EnerJex Resources, Inc. and Subsidiaries
Consolidated Statement of Stockholders' Equity
| Equity Based | Accumulated Other | Total Stockholders’ Equity EnerJex | Non Controlling Interest | Total | ||||||||||||||||||||||||||||||||||||||||||||
| Preferred Stock | Common Stock | Treasury | Compensation | �� | Comprehensive | Paid in | Retained | Resources, | In | Stockholders’ | ||||||||||||||||||||||||||||||||||||||
| Shares | Amount | Shares | Amount | Stock | Unearned | Income | Capital | Deficit | Inc. | Subsidiary | Equity | |||||||||||||||||||||||||||||||||||||
| Balance, January 1, 2011 | 4,779,460 | $ | 4,780 | 67,459,869 | $ | 67,460 | $ | - | $ | - | $ | - | $ | 37,661,719 | $ | (18,355,991 | ) | $ | 19,377,968 | $ | - | $ | 19,377,968 | |||||||||||||||||||||||||
| Stock sold | - | - | 5,726,660 | 5,727 | - | - | - | 3,430,269 | - | 3,435,996 | - | 3,435,996 | ||||||||||||||||||||||||||||||||||||
| Stock issued for oil asset and services | - | - | 225,000 | 225 | - | - | - | 122,275 | - | 122,500 | - | 122,500 | ||||||||||||||||||||||||||||||||||||
| Stock options and warrants issued | - | - | - | - | - | (536,591 | ) | - | 536,591 | - | - | - | - | |||||||||||||||||||||||||||||||||||
| Amortization of stock options and warrants | - | - | - | - | - | 305,778 | - | - | - | 305,778 | - | 305,778 | ||||||||||||||||||||||||||||||||||||
| Acquisition of treasury stock | - | - | - | - | (1,500,000 | ) | - | - | - | - | (1,500,000 | ) | - | (1,500,000 | ||||||||||||||||||||||||||||||||||
| Accumulated other comprehensive loss | - | - | - | - | - | - | (552,589 | ) | - | - | (552,589 | ) | - | (552,589 | ||||||||||||||||||||||||||||||||||
| Gain on sale of non controlling interest in subsidiary | - | - | - | - | - | - | - | 1,805,632 | - | 1,805,632 | 544,368 | 2,350,000 | ||||||||||||||||||||||||||||||||||||
| Dividends paid on preferred stock | - | - | - | - | - | - | - | - | (56,263 | ) | (56,263 | ) | - | (56,263 | ||||||||||||||||||||||||||||||||||
| Net loss for the year | - | - | - | - | - | - | - | - | (2,038,622 | ) | (2,038,622 | ) | 21,360 | (2,017,262 | ||||||||||||||||||||||||||||||||||
| Balance, December 31, 2011 | 4,779,460 | 4,780 | 73,411,529 | 73,412 | (1,500,000 | ) | (230,813 | ) | (552,589 | ) | 43,556,486 | (20,450,876 | ) | 20,900,400 | 565,728 | 21,466,128 | ||||||||||||||||||||||||||||||||
| Stock Options and Warrants Issued | - | - | - | - | - | - | - | 252,925 | - | 252,925 | - | - | ||||||||||||||||||||||||||||||||||||
| Amortization of Stock Options | - | - | - | - | - | 76,937 | - | - | - | 76,938 | - | - | ||||||||||||||||||||||||||||||||||||
| Stock Issued for Services | - | - | 175,000 | 175 | - | - | - | 122,226 | - | 122,401 | - | - | ||||||||||||||||||||||||||||||||||||
| Acquisition of Treasury Stock | - | - | - | - | (1,051,000 | ) | - | - | - | - | (1,051,000 | ) | - | - | ||||||||||||||||||||||||||||||||||
| Gain on Sale of Partnership Interest | - | - | - | - | - | - | - | 1,420,459 | - | 1,420,459 | 1,229,540 | - | ||||||||||||||||||||||||||||||||||||
| Distribution of Non-Controlling Interest | - | - | - | - | - | - | - | - | - | - | (592,936 | ) | - | |||||||||||||||||||||||||||||||||||
| Liquidation of Non-Controlling Interest | - | - | - | - | - | - | - | - | - | - | (1,597,460 | ) | - | |||||||||||||||||||||||||||||||||||
| Dividends Paid on Preferred Stock | - | - | - | - | - | - | - | - | (608,459 | ) | (608,459 | ) | - | - | ||||||||||||||||||||||||||||||||||
| Net Income for the Year | - | - | - | - | - | - | - | - | 345,992 | 345,992 | 395,128 | - | ||||||||||||||||||||||||||||||||||||
| Balance December 31,2012 | 4,779,460 | $ | 4,780 | $ | 73,586,529 | $ | 73,587 | $ | (2,551,000 | ) | $ | (153,876 | ) | $ | (552,589 | ) | $ | 45,352,096 | $ | (20,713,343 | ) | $ | 21,459,655 | $ | - | $ | 21,634,419 | |||||||||||||||||||||
See Notes to Consolidated Financial Statements.
| F-34 |
EnerJex Resources, Inc. and Subsidiaries
Consolidated Statements of Cash Flows
| Year Ended December 31, | ||||||||
| 2012 | 2011 | |||||||
| Cash flows from operating activities | ||||||||
| Net Income (loss) | $ | 741,120 | $ | (2,017,262 | ) | |||
| Depreciation, depletion and amortization | 1,633,467 | 1,128,712 | ||||||
| Stock, options and warrants issued for services | 285,230 | 368,278 | ||||||
| Accretion of asset retirement obligation | 93,973 | 87,437 | ||||||
| (Gain) on derivatives | (927,039 | ) | (469,495 | ) | ||||
| (Gain) on sale of fixed assets | (1,378 | ) | - | |||||
| Adjustments to reconcile net income (loss) to cash from operating activities: | ||||||||
| Accounts receivable | 232,443 | (1,097,018 | ) | |||||
| Deposits and prepaid expenses | (93,123 | ) | 30,032 | |||||
| Accounts payable | 28,398 | 1,245,844 | ||||||
| Accrued liabilities | 291,652 | (38,021 | ) | |||||
| Cash flows from operating activities | 2,284,743 | (761,493 | ) | |||||
| Cash flows from investing activities | ||||||||
| Purchase of Treasury Stock | (226,000 | ) | (1,500,000 | ) | ||||
| Purchase of fixed assets | (115,274 | ) | (276,294 | ) | ||||
| Additions to oil properties | (10,247,539 | ) | (6,288,695 | ) | ||||
| Sale of oil properties | - | 3,825,000 | ||||||
| Proceeds from sale of vehicles | 11,240 | - | ||||||
| Cash flows from investing activities | (10,577,573 | ) | (4,239,989 | ) | ||||
| Cash flows from financing activities | ||||||||
| Sale of marketable securities | - | 1,400,000 | ||||||
| Sale of common stock | - | 3,435,996 | ||||||
| Sale of non-controlling interest in subsidiary | 2,650,000 | 2,350,000 | ||||||
| Dividend paid | (433,696 | ) | (56,263 | ) | ||||
| Borrowings on long-term debt | 4,700,000 | 700,000 | ||||||
| Distribution to non-controlling interest in subsidiary | (592,936 | ) | - | |||||
| Payments on long-term debt | (33,484 | ) | (3,019,630 | ) | ||||
| Cash flows from financing activities | 6,289,884 | 4,810,103 | ||||||
| Increase (decrease) in cash and cash equivalents | (2,002,946 | ) | (191,379 | ) | ||||
| Cash and cash equivalents, beginning | 2,770,440 | 2,961,819 | ||||||
| Cash and cash equivalents, end | $ | 767,494 | $ | 2,770,440 | ||||
| Supplemental disclosures: | ||||||||
| Interest paid | $ | 195,125 | $ | 445,365 | ||||
| Income taxes paid | $ | - | $ | - | ||||
| Non-cash transactions: | ||||||||
| Share-based payments issued for services | $ | 452,263 | $ | 368,278 | ||||
| Stock issued for oil properties and supporting assets | - | 60,000 | ||||||
| Treasury stock purchased with a note payable | $ | 825,000 | $ | - | ||||
| Preferred dividends payable | 174,763 | - | ||||||
See Notes to Consolidated Financial Statements.
| F-35 |
EnerJex Resources, Inc.
Notes to Consolidated Financial Statements
Note 1 - Summary of Accounting Policies
Basis of Presentation
Our consolidated financial statements have been prepared assuming thatin accordance with accounting principles generally accepted in the Company will continue asUnited States. Our operations are considered to fall within a going concern. As discussedsingle industry segment, which are the acquisition, development, exploitation and production of crude oil properties in Note 2the United States. Our consolidated financial statements include our wholly owned subsidiaries and our majority owned subsidiary Rantoul Partners (through December 31, 2012). On December 31, 2012, the Rantoul Partners subsidiary was liquidated. All significant intercompany balances and transactions have been eliminated upon consolidation. Certain reclassifications have been made to the prior year financial statements to conform to the Company has suffered recurring losses and had negative cash flows that raise substantial doubt about the Company's ability to continue as a going concern. Management's plans in regard to these matters are described in the Note 2. The financial statements do not include any adjustments that might result from the outcome of this uncertainty.
| March 31, | ||||||||
| 2009 | 2008 | |||||||
| Assets | ||||||||
| Current assets: | ||||||||
| Cash | $ | 127,585 | $ | 951,004 | ||||
| Accounts receivable | 462,044 | 227,055 | ||||||
| Prepaid debt issue costs | 45,929 | 157,191 | ||||||
| Deposits and prepaid expenses | 263,383 | 176,345 | ||||||
| Total current assets | 898,941 | 1,511,595 | ||||||
| Fixed assets | 365,019 | 185,299 | ||||||
| Less: Accumulated depreciation | 63,988 | 30,982 | ||||||
| Total fixed assets | 301,031 | 154,317 | ||||||
| Other assets: | ||||||||
| Prepaid debt issue costs | - | 157,191 | ||||||
| Oil and gas properties using full-cost accounting: | ||||||||
| Properties not subject to amortization | 31,183 | 62,216 | ||||||
| Properties subject to amortization | 6,449,023 | 8,982,510 | ||||||
| Total other assets | 6,480,206 | 9,201,917 | ||||||
| Total assets | $ | 7,680,178 | $ | 10,867,829 | ||||
| Liabilities and Stockholders’ Equity (Deficit) | ||||||||
| Current liabilities: | ||||||||
| Accounts payable | $ | 1,016,168 | $ | 416,834 | ||||
| Accrued liabilities | 87,811 | 70,461 | ||||||
| Notes payable | - | 965,000 | ||||||
| Deferred payments from Euramerica development | - | 251,951 | ||||||
| Long-term debt, current | 1,723,036 | 412,930 | ||||||
| Total current liabilities | 2,827,015 | 2,117,176 | ||||||
| Asset retirement obligation | 803,624 | 459,689 | ||||||
| Convertible note payable | 25,000 | 25,000 | ||||||
| Long-term debt, net of discount of $596,108 | 7,818,163 | 6,831,972 | ||||||
| Total liabilities | 11,473,802 | 9,433,837 | ||||||
| Contingencies and commitments | ||||||||
| Stockholders’ Equity (Deficit): | ||||||||
| Preferred stock, $0.001 par value, 10,000,000 shares authorized, no shares issued and outstanding | - | - | ||||||
| Common stock, $0.001 par value, 100,000,000 shares authorized; shares issued and outstanding –4,443,512 at March 31, 2009 and 4,440,651 at March 31, 2008 | 4,444 | 4,441 | ||||||
| Paid in capital | 8,932,906 | 8,853,457 | ||||||
| Retained (deficit) | (12,730,974 | ) | (7,423,906 | ) | ||||
| Total stockholders’ equity (deficit) | (3,793,624 | ) | 1,433,992 | |||||
| Total liabilities and stockholders’ equity (deficit) | $ | 7,680,178 | $ | 10,867,829 | ||||
| For the Fiscal Years Ended | ||||||||
| March 31, | ||||||||
| 2009 | 2008 | |||||||
| Oil and natural gas revenues | $ | 6,436,805 | $ | 3,602,798 | ||||
| Expenses: | ||||||||
| Direct operating costs | 2,637,333 | 1,795,188 | ||||||
| Depreciation, depletion and amortization | 911,293 | 935,330 | ||||||
| Impairment of oil and gas properties | 4,777,723 | - | ||||||
| Professional fees | 1,320,332 | 1,226,998 | ||||||
| Salaries | 849,340 | 1,703,099 | ||||||
| Administrative expense | 1,392,645 | 887,872 | ||||||
| Total expenses | 11,888,666 | 6,548,487 | ||||||
| Loss from operations | (5,451,861 | ) | (2,945,689 | ) | ||||
| Other income (expense): | ||||||||
| Interest expense | (882,426 | ) | (792,448 | ) | ||||
| Loan interest accretion | (2,814,095 | ) | (1,089,798 | ) | ||||
| Gain on liquidation of hedging instrument | 3,879,050 | - | ||||||
| Other Gain/(Loss) | (37,736 | ) | - | |||||
| Total other income (expense) | 144,793 | (1,882,246 | ) | |||||
| Net income - (loss) | $ | (5,307,068 | ) | $ | (4,827,935 | ) | ||
| Weighted average shares outstanding - basic | 4,443,249 | 4,284,144 | ||||||
| Net income (loss) per share - basic | $ | (1.19 | ) | $ | (1.13 | ) | ||
Common Stock | ||||||||||||||||||||||||
Shares | Par��Value | Owed but not issued | Paid in Capital | Retained Deficit | Total Stockholders’ Equity (Deficit) | |||||||||||||||||||
| Balance, April 1, 2007 | 2,635,731 | $ | 2,636 | $ | 3 | $ | 2,548,742 | $ | ( 2,595,971 | ) | $ | (44,590 | ) | |||||||||||
| Stock sold | 1,800,000 | 1,800 | - | 4,311,956 | - | 4,313,756 | ||||||||||||||||||
| Stock issued for services | 1,920 | 2 | - | 14,998 | - | 15,000 | ||||||||||||||||||
| Previously authorized but unissued stock | 3,000 | 3 | (3 | ) | - | - | - | |||||||||||||||||
| Stock options issued for services | - | - | - | 1,977,761 | - | 1,977,761 | ||||||||||||||||||
| Net (loss) for the year | - | - | - | - | (4,827,935 | ) | (4,827,935 | ) | ||||||||||||||||
| Balance, March 31, 2008 | 4,440,651 | 4,441 | - | 8,853,457 | (7,423,906 | ) | 1,433,992 | |||||||||||||||||
| Stock options issued for services | - | - | - | 67,452 | - | 67,452 | ||||||||||||||||||
| Stock issued for services | 2,182 | 2 | - | 11,998 | - | 12,000 | ||||||||||||||||||
| Stock issued in reverse stock split | 679 | 1 | - | (1 | ) | - | - | |||||||||||||||||
| Net loss for the year | - | - | - | - | $ | (5,307,068 | ) | (5,307,068 | ) | |||||||||||||||
| Balance, March 31, 2009 | 4,443,512 | $ | 4,444 | $ | - | $ | 8,932,906 | $ | ( 12,730,974 | ) | $ | (3,793,624 | ) | |||||||||||
| For the Fiscal Years Ended | ||||||||
| March 31, | ||||||||
| 2009 | 2008 | |||||||
| Cash flows from operating activities | ||||||||
| Net (loss) | $ | (5,307,068 | ) | $ | (4,827,935 | ) | ||
| Depreciation and depletion | 950,357 | 935,330 | ||||||
| Debt issue cost amortization | 157,191 | 152,453 | ||||||
| Stock and options issued for services | 79,452 | 1,992,761 | ||||||
| Accretion of interest on long-term debt discount | 2,814,095 | 1,089,798 | ||||||
| Accretion of asset retirement obligation | 60,864 | 30,331 | ||||||
| Impairment of oil & gas properties | 4,777,723 | - | ||||||
| Adjustments to reconcile net (loss) to cash used in operating activities: | ||||||||
| Accounts receivable | (234,989 | ) | (222,917 | ) | ||||
| Notes and interest receivable | - | 10,300 | ||||||
| Deposits and prepaid expenses | 24,224 | (169,672 | ) | |||||
| Accounts payable | 599,334 | 374,535 | ||||||
| Accrued liabilities | 17,350 | (25,429 | ) | |||||
| Deferred payment from Euramerica for development | (251,951 | ) | 251,951 | |||||
| Cash used in operating activities | 3,686,582 | (408,494 | ) | |||||
| Cash flows from investing activities | ||||||||
| Purchase of fixed assets | (204,200 | ) | (149,799 | ) | ||||
| Additions to oil & gas properties | (3,123,003 | ) | (9,530,321 | ) | ||||
| Sale of oil & gas properties | 300,000 | 300,000 | ||||||
| Note and interest receivable from officer | - | 23,100 | ||||||
| Proceeds from sale of vehicle | - | |||||||
| Cash used in investing activities | (3,027,203 | ) | (9,357,020 | ) | ||||
| Cash flows from financing activities | ||||||||
| Proceeds from (repayment of) note payable, net | (965,000 | ) | 615,000 | |||||
| Proceeds from sales of common stock | - | 4,313,756 | ||||||
| Debt issue costs | (466,835 | ) | ||||||
| Borrowings on long-term debt | 11,274,843 | 6,344,816 | ||||||
| Payments on long-term debt | (11,792,641 | ) | (189,712 | ) | ||||
| Cash provided from financing activities | (1,482,798 | ) | 10,617,025 | |||||
| Increase (decrease) in cash and cash equivalents | (823,419 | ) | 851,511 | |||||
| Cash and cash equivalents, beginning | 951,004 | 99,493 | ||||||
| Cash and cash equivalents, end | $ | 127,585 | $ | 951,004 | ||||
| Supplemental disclosures: | ||||||||
| Interest paid | $ | 768,053 | $ | 733,972 | ||||
| Income taxes paid | $ | - | $ | - | ||||
| Non-cash transactions: | ||||||||
| Share-based payments issued for services | $ | - | $ | 280,591 | ||||
Nature of Business
We are an independent energy company engaged in the business of producing and selling crude oil and natural gas.oil. This crude oil and natural gas is obtained primarily by the acquisition and subsequent exploration and development of mineral leases. Development and exploration may include drilling new exploratory or development wells on these leases. These operations are conducted primarily in Eastern Kansas.
Use of Consolidation
The preparation of consolidated financial statements includein conformity with generally accepted accounting principles requires management to make estimates and assumptions that affect the accountsreported amounts of our wholly-owned subsidiaries, EnerJex Kansas, Inc., DD Energy, Inc.
Trade Accounts Receivable
Trade accounts receivable are recorded at the invoiced amount and do not bear any interest. We regularly review receivables to insure that the amounts will be collected and establish or adjust an allowance for uncollectible amounts as necessary using the specific identification method. Account balances are charged off against the allowance after all means of collection have been exhausted and the potential for recovery is considered remote. There were no reserves for uncollectible amounts in the periods presented.
Share-Based Payments
The value we assign to the options and warrants that we issue is based on the fair market value as calculated by the Black-Scholes pricing model. To perform a calculation of the value of our options and warrants, we determine an estimate of the volatility of our stock. We need to estimate volatility because there has not been enough trading of our stock to determine an appropriate measure of volatility. We believe our estimate of volatility is reasonable, and we review the assumptions used to determine this whenever we issue a new equity instruments. If we have a material error in our estimate of the volatility of our stock, our expenses could be understated or overstated.
Income Taxes
Income taxes are accounted for income taxes under the Statement of Financial Accounting Standards “SFAS” Statement 109, “Accounting for Income Taxes”. The asset and liability approach requires the recognition of deferredmethod. Deferred tax liabilities and assets for the expected future tax consequences of temporary differences between the carrying amounts and the tax basis of assets and liabilities. The provision for income taxes differs from the amount currently payable becauseliabilities are recognized when items of temporary differences in the recognition of certain income and expense items for financial reporting and tax reporting purposes.
We routinely assess the reliability of our deferred tax assets. If we conclude that it is more likely than not that some portion or all of the deferred tax assets will not be realized under accounting standards, the tax asset is reduced by a valuation allowance. In addition we routinely assess uncertain tax positions, and accrue for Income Taxes”. As a result, we apply atax positions that are not more-likely-than-not recognition threshold for all tax uncertainties. FIN 48 only allows the recognition of those tax benefits that have a greater than fifty percent likelihood of beingto be sustained upon examination by the taxing authorities. As
Uncertain Tax Positions
We follow guidance in Topic 740 of the Codification for its accounting for uncertain tax positions. Topic 740 prescribes guidance for the financial statement recognition and measurement of a result of implementing FIN 48,tax position taken or expected to be taken in a tax return. To recognize a tax position, we have reviewed ourdetermine whether it is more-likely-than-not that the tax positions and determined there were no outstanding or retroactive tax positions with less than a 50% likelihood of beingposition will be sustained upon examination, by the taxing authorities, therefore the implementationincluding resolution of this standard has not had a material effectany related appeals or litigation, based solely on the Company.
We classify tax-relatedhave no liability for unrecognized tax benefits recorded as of December 31, 2012, and 2011. Accordingly, there is no amount of unrecognized tax benefits that, if recognized, would affect the effective tax rate and there is no amount of interest or penalties currently recognized in the statement of operations or statement of financial position as of December 31, 2012. In addition, we do not believe that there are any positions for which it is reasonably possible that the total amounts of unrecognized tax benefits will significantly increase or decrease within the next twelve months. We recognize related interest and net interest on income taxespenalties as a component of income tax expense. As
Tax years open for audit by federal tax authorities as of MarchDecember 31, 2012, are the years ended December 31, 2009, 2010, 2011 and 2008, no income tax expense had been incurred.
Fair Value Measurements
Accounting guidance establishes a single authoritative definition of Financial Instruments
Cash and Cash Equivalents
We consider all highly liquid investment instruments purchased with original maturities of three months or less to be cash equivalents for purposes of the consolidated statements of cash flows and other statements. We maintain cash on deposit, which, at times, exceed federally insured limits. We have not experienced any losses on such accounts and believe we are not exposed to any significant credit risk on cash and equivalents.
Revenue Recognition and Imbalances
Oil and gas revenues are recognized net of royalties when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collection of the revenue is probable. Cash received relating to future revenues is deferred and recognized when all revenue recognition criteria are met.
Property and Equipment
Property and equipment are recorded at cost. Depreciation is on a straight-line method using the estimated lives of the assets. (3-15 years). Expenditures for maintenance and repairs are charged to expense.
Debt Issue Costs
Debt issuance costs incurred are capitalized and subsequently amortized over the term of the related debt on the straight-line method of amortization over the estimated life of the debt.
Oil and Gas Properties
We follow the full-cost method of accounting under which all costs associated with property acquisition, exploration and development activities are capitalized. We also capitalize internal costs that can be directly identified with our acquisition, exploration and development activities and do not include any costs related to production, general corporate overhead or similar activities.
Under the full-cost method, capitalized costs are amortized on a composite unit-of-production method based on proved gas and oil reserves. Depreciation, depletion and amortization expense is also based on the amount of estimated reserves. If we maintain the same level of production year over year, the depreciation, depletion and amortization expense may be significantly different if our estimate of remaining reserves changes significantly. Proceeds from the sale of properties are accounted for as reductions of capitalized costs unless such sales involve a significant change in the relationship between costs and the value of proved reserves or the underlying value of unproved properties, in which case a gain or loss is recognized. The costs of unproved properties are excluded from amortization until the properties are evaluated. We review all of our unevaluated properties quarterly to determine whether or not and to what extent proved reserves have been assigned to the properties, and otherwise if impairment has occurred. Unevaluated properties are assessed individually when individual costs are significant.
We review the carrying value of our gas and oil properties under the full-cost accounting rules of the SEC on a quarterly basis. This quarterly review is referred to as a ceiling test. Under the ceiling test, capitalized costs, less accumulated amortization and related deferred income taxes, may not exceed an amount equal to the sum of the present value of estimated future net revenues (adjusted for cash flow hedges) less estimated future expenditures to be incurred in developing and producing the proved reserves, less any related income tax effects. In calculating future net revenues, current SEC regulations require us to utilize prices at the end of the appropriate quarterly period. Such prices are utilized except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts, including the effects of derivatives qualifying as cash flow hedges. Two primary factors impacting this test are reserve levels and current prices, and their associated impact on the present value of estimated future net revenues. Revisions to estimates of gas and oil reserves and/or an increase or decrease in prices can have a material impact on the present value of estimated future net revenues. Any excess of the net book value, less deferred income taxes, is generally written off as an expense. Under SEC regulations, the excess above the ceiling is not expensed (or is reduced) if, subsequent to the end of the period, but prior to the release of the financial statements, gas and oil prices increase sufficiently such that an excess above the ceiling would have been eliminated (or reduced) if the increased prices were used in the calculations.
The estimates of proved crude oil reserves utilized in December 2008,the preparation of the financial statements are estimated in accordance with guidelines established by the Securities and Exchange Commission (“("SEC”) issued new regulations for oil and gas reserve reportingthe Financial Accounting Standards Board ("FASB"), which go into effect effective for fiscal years ending on or after December 31, 2009. One of the key elements of the new regulations relate to the commodity prices which are used to calculate reserves and their present value. The new regulations provide for disclosure of oil and gas reserves evaluated using annual average prices based on the prices in effect on the first day of each month rather than the current regulations which utilize commodity prices on the last day of the year.
Long-Lived Assets
Impairment of long-lived assets is recorded when indicators of impairment are present and the undiscounted cash flows estimated to be generated by those assets are less than the assets’assets' carrying value. The carrying value of the assets is then reduced to their estimated fair value that is usually measured based on an estimate of future discounted cash flows.
Asset Retirement Obligations
The asset retirement obligation relates to the plug and abandonment costs when our wells are no longer useful. We determine the value of the liability by obtaining quotes for this service and estimate the increase we will face in the future. We then discount the future value based on an intrinsic interest rate that is appropriate for us. If costs rise more than what we have expected there could be additional charges in the future, however, we monitor the costs of the abandoned wells and we will adjust this liability if necessary.
Major Purchasers
For the years ended MarchDecember 31, 20092012, and 20082011 we sold all of our natural gas productionproduced oil to one purchaser. We sold all of our oil production to one purchaser during fiscal 2009Coffeyville Resources, Plains Marketing, L.P., and toSunoco, Inc. on a single, but different purchasermonth-to-month basis.
Marketable Securities Available for Sale
The Company classifies its marketable equity securities as available-for-sale and they are carried at fair market value, with the unrealized gains and losses included in fiscal 2008.
Reclassifications
Certain reclassifications have been made to prior periods to conform to current presentation.presentations.
| F-38 |
Recent Accounting Pronouncements Applicable to the Company
The Company does not believe there are any recently issued, but not yet effective; accounting standards that would have a significant impact on the Company’s financial position or results of operations.
Note 2 – Going Concern
The accompanying consolidated financial statementsSeries A preferred stock is convertible into 4,779,460 shares of our common stock, and the Series A preferred stock, by its terms, shall convert into common stock on a one-to-one basis (subject to adjustment) once the cumulative dividends paid with regard to such stock equal to original principal value of $1.00 per share. In the event of liquidation, the holders of our Series A preferred stock would receive priority liquidation payments before payments to common shareholders equal to the amount of the stated value of the preferred stock before any distributions would be made to our common shareholders. The preferred stockholders have been prepared assumingthe right, by majority vote of the shares of preferred stock, to generally approve any issuances by us of equity that we will continue as a going concern. Our abilityis senior to continue as a going concern is dependent upon attaining profitable operations based onor equal in rights to the developmentpreferred stock.
We are required by the terms of products that can be sold. We intendour Series A preferred stock to use borrowings, equity and asset sales,declare dividends each calendar quarter in an aggregate amount equal to one-third of our adjusted net cash from operating activities reduced by any principal amount of debt repayment in such calendar quarter to institutional lenders and other strategic initiatives to mitigatesecured creditors. Dividends of $433,696 and $56,263 were paid for the affectsyears ended December 31, 2012, and 2011 respectively. A dividend of our cash position, however, no assurance can be given that debt or equity financing, if and when required,$174,763 will be available. The financial statements do not include any adjustments relatingpaid in the second quarter of 2013 to the recoverability and classificationpreferred shareholders of recorded assets and classificationrecord as of liabilities that might be necessary should we be unable to continue in existence.
Stock transactions in fiscal 2009:
We issued 2,18260,000 shares at $0.77 per shares to an Investor Relations firm in exchange for services. The market value of the stock at the date of issuance was $0.77 per share. We also issued 75,000 shares to a Director of the Company for services and 40,000 shares to an employee of the Company. The market price at the date of issuance for these shares was $0.60 and $0.78 respectively.
On November 30, 2012, the Company purchased two million shares of stock from a shareholder of the Company for $323,035 in cash (including an option payment that we previously made to the selling stockholder) and a note payable of $825,000 bearing interest at a rate per annum of twenty-four hundredths percent (0.24%) (See footnote 13).
Stock transactions in fiscal year ended December 31, 2011
On March 31, 2011, we issued 5,727,660 shares that were sold at a price of $0.60 per share.
On March 31, 2011, we entered into a Stock Redemption Agreement with Working Interest Group, LLC whereby we repurchased 3,750,000 shares of common stock at a price of $0.40 per share.
On November 14, 2011, we agreed to issue 100,000 shares for the purchase of assets.
On December 31, 2011, we agreed to issue 25,000 shares of our common stock as compensation to a Director and chairman of our Audit Committeeboard member for services over the next year. For the year ended March 31, 2009, we recorded director compensation in the amount $13,000.
Option and Warrant transactions:
Officers (including officers who are members of the boardBoard of directors)Directors), directors, employees and consultants are eligible to receive options under our stock option plans. We administer the stock option plans and we determine those persons to whom options will be granted, the number of options to be granted, the provisions applicable to each grant and the time periods during which the options may be exercised. No options may be granted more than ten years after the date of the adoption of the stock option plans.
Each option granted under the stock option plans will be exercisable for a term of not more than ten years after the date of grant. Certain other restrictions will apply in connection with the plans when some awards may be exercised. In the event of a change of control (as defined in the stock option plans), the vesting date on which all options outstanding under the stock option plans may first be exercised will be accelerated. Generally, all options terminate 90 days after a change of control.
2000-2001 Stock Option Plan
The Board of Directors approved a stock option plan and our stockholders ratified the plan on September 25, 2000. The total number of options that can be granted under the plan is 200,000 shares. At March 31, 2009, we had granted 200,000 non-qualified options under this plan.
Stock Option Plan
On May 4, 2007, we amended and restated the EnerJex Resources, Inc. Stock Option Plan to rename the plan and to increase the number of shares issuable under the plan to 1,000,000. Our stockholders approved this plan in September of 2007. On October 14, 2008 our stockholders approved a proposal to amend and restate the 2002-2003 Stock Option Plan to (i) rename it the EnerJex Resources, Inc. Stock Incentive Plan (the "Stock Incentive Plan"), (ii) increase the maximum number of shares of our common stock that may be issued under the Stock Incentive Plan from 1,000,000 to 1,250,000, and (iii) add restricted stock as an eligible award that can be granted under the Stock Incentive Plan. At MarchDecember 31, 2009,2011, there were 900,000 options outstanding.
On December 31, 2010, we had granted 238,500 non-qualified900,000 options under this plan.
On December 1, 2012, we granted warrants785,000 options that vest ratably every six months over a three year period to purchase 75,000four employees of the company. The fair value of the option on the date of the grant was calculated using the Black-Scholes model was $167,032 using the following weighted average assumptions: exercise price of $0.70 per share; common stock price of $0.56 per share; volatility of 67%; term of three years; dividend yield of 0%; interest rate of .47%. The amount recognized as expense in the years ended December 31, 2012, was $18,825 and the amount of expense to be recognized in future periods is $148,208. There were no options vested at December 31, 2012.
New Stock Incentive Plan
Because there are not available under our existing 2000/2001 Stock Option Plan or our 2002-2003 Stock Option Plan sufficient shares to cover options that we intend to grant, and because those existing plans are dated and would not allow us to grant tax-qualified incentive stock options, we intend to seek stockholder approval of a new stock incentive plan and to reserve thereunder up to approximately 5,000,000 shares of our common stock as partial payment for services rendered in connectionthe granting of options and issuance of restricted shares to our employees, officers, directors, and consultants. We have entered into an agreement with Douglas M. Wright, our financing activities.chief financial officer, that if he is employed with us when that plan has been approved by our stockholders, then we will grant to him under the new stock incentive plan an option for the purchase of 750,000 shares of stock, subject to a vesting arrangement.
Warrant Transactions
On March 31, 2011, we granted 2,838,330 Warrants to each investor that entered into the Securities Purchase Agreement for additional consideration, each investor received a stock purchase warrant to purchase 1 share of common stock at a price of $0.90 per share, for each 2 shares of common stock purchased.
Each Warrant was exercisable until December 31, 2011. The warrants have anfair value at the date of the grant was calculated using the Black-Scholes model and totaled $74,164, using the following weighted average assumptions: exercise price of $3.00 and$0.90 per share; common stock price of $0.85 per share; volatility of 42%; term of nine months; dividend yield of 0%; interest rate of 0.30%. On December 31, 2011, the warrants were extended for an additional nine months to expire on April 11, 2010.September 30, 2012. The fair value at the date of the warrantsextension was calculated using the Black-Scholes model and totaled $154,676, using the following weighted average assumptions: exercise price of $0.90 per share; common stock price of $0.90 per share; volatility of 71%; term of nine months; dividend yield of 0%; interest rate of 0.25%. The amount recognized as expense in the year ended December 31, 2011, was based on an estimate of the number of warrants that would be exercised and totaled $228,840. On September 30, 2012, the warrants were cancelled unexercised.
On May 31, 2012, we granted 250,000 Warrants to an investor relations firm for investor relations services to be performed over the next two years. Each warrant is exercisable until May 31, 2014. The fair value at the date of grant was calculated using the Black-Scholes pricing model and totaled $280,591 (approximately $3.75approximately $86,000 using the following assumptions. The exercise price is $0.70 per warrant).share. The following assumptions were used inmarket price of our stock at the valuation: stock price-$1.00; exercise price-$0.60; life- 3 years; volatility- 106%; yield-4.66%.grant date was $0.75 per share. We have included the valueassumed volatility of the warrants with the loan82%, a dividend yield of 0.0%, an interest rate of 0.30% and equity transaction costs (See Note 5).
A summary of stock options and warrants is as follows:
| Options | Weighted Ave. Exercise Price | Warrants | Weighted Ave. Exercise Price | |||||||||||||
| Outstanding April 1, 2007 | 60,000 | $ | 6.25 | - | - | |||||||||||
| Granted | 458,500 | 6.30 | 75,000 | $ | 3.00 | |||||||||||
| Cancelled | (60,000 | ) | (6.25 | ) | - | - | ||||||||||
| Exercised | - | - | - | - | ||||||||||||
| Outstanding March 31, 2008 | 458,500 | $ | 6.30 | 75,000 | $ | 3.00 | ||||||||||
| Granted | - | - | - | - | ||||||||||||
| Cancelled | (20,000 | ) | (6.25 | ) | - | - | ||||||||||
| Exercised | - | - | - | - | ||||||||||||
| Outstanding March 31, 2009 | 438,500 | $ | 6.30 | 75,000 | $ | 3.00 | ||||||||||
| Options | Weighted Ave. Exercise Price | Warrants | Weighted Ave. Exercise Price | |||||||||||||
| Outstanding January 1, 2011 | 900,000 | $ | 0.40 | - | $ | - | ||||||||||
| Granted | - | - | 2,838,330 | 0.90 | ||||||||||||
| Cancelled | - | - | - | - | ||||||||||||
| Exercised | - | - | - | - | ||||||||||||
| Outstanding December 31, 2011 | 900,000 | $ | 0.40 | 2,838,330 | $ | 0.90 | ||||||||||
| Granted | 785,000 | 0.70 | 250,000 | 0.70 | ||||||||||||
| Cancelled | - | - | (2,838,330 | ) | (0.90 | ) | ||||||||||
| Exercised | - | - | - | - | ||||||||||||
| Outstanding December 31, 2012 | 1,685,000 | $ | 0.54 | 250,000 | $ | 0.70 | ||||||||||
Note 4 –3 - Asset Retirement Obligation
Our asset retirement obligations relate to the abandonment of oil and natural gas wells. The amounts recognized are based on numerous estimates and assumptions, including future retirement costs, inflation rates and credit adjusted risk-free interest rates. The following shows the changes in asset retirement obligations:
| Asset retirement obligation at April 1, 2007 | $ | 23,908 | ||
| Liabilities incurred during the period | 405,450 | |||
| Liabilities settled during the period | - | |||
| Accretion | 30,331 | |||
| Asset retirement obligations, March 31, 2008 | 459,689 | |||
| Liabilities incurred during the period | 283,071 | |||
| Liabilities settled during the period | - | |||
| Accretion | 60,864 | |||
| Asset retirement obligations, March 31, 2009 | $ | 803,624 |
| Asset retirement obligations, January 1, 2011 | $ | 883,066 | ||
| Liabilities incurred during the period | 297,800 | |||
| Liabilities settled during the period | (359,513 | ) | ||
| Accretion | 87,437 | |||
| Asset retirement obligations, December 31, 2011 | 908,790 | |||
| Liabilities incurred during the period | 347,018 | |||
| Liabilities settled during the year | (1,427 | ) | ||
| Accretion | 81,770 | |||
| Asset retirement obligations, December 31, 2012 | $ | 1,336,151 |
Note 54 - Long-Term Debt
Senior Secured Credit Facility
On JulyOctober 3, 2008, EnerJex, EnerJex Kansas,2011, the Company and DD Energy, Inc., EnerJex Kansas, Inc., Black Sable Energy, LLC and Working Interest, LLC ("Borrowers") entered into a three-year $50 million Senior Securedan Amended and Restated Credit Facility (the “Credit Facility”)Agreement with Texas Capital Bank, N.A. Borrowingsand other financial institutions and banks that may become a party to the Credit Agreement from time to time. The facilities provided under the Amended and Restated Credit FacilityAgreement are to be used to refinance Borrowers prior outstanding revolving loan facility with Bank, dated July 3, 2008, and for working capital and general corporate purposes.
At our option, loans under the facility will bear stated interest based on the Base Rate plus Base Rate Margin, or Floating Rate plus Floating Rate Margin (as those terms are defined in the Credit Agreement). The Base Rate will be, subjectfor any day, a fluctuating rate per annum equal to the higher of (a) the Federal Funds Rate plus 0.50% and (b) the Bank's prime rate.
The Floating Rate shall mean, at Borrower's option, a borrowing base limitationper annum interest rate equal to (i) the Eurodollar Rate plus Eurodollar Margin, or (ii) the Base Rate plus Base Rate Margin (as those terms are defined in the Amended and Restated Credit Agreement). Eurodollar borrowings may be for one, two, three, or six months, as selected by the Borrowers. The margins for all loans are based on our current proved oila pricing grid ranging from 0.00% to 0.75% for the Base Rate Margin and gas reserves2.25% to 3.00% for the Floating Rate Margin based on the Company's Borrowing Base Utilization Percentage (as defined in the Amended and will be subjectRestated Credit Agreement).
We entered into a First Amendment to semi-annual redeterminationsAmended and interim adjustments.Restated Credit Agreement and Second Amended and Restated Promissory Note in the amount of $50,000,000 with the Texas Capital Bank, which closed on December 15, 2011. The initial borrowing base was set at $10.75 millionAmendment reflects the addition of Rantoul Partners, as an additional Borrower and was reduced to $7.428 millionadds as additional security for the loans the assets held by Rantoul Partners.
We entered into a Second Amendment and Restated Credit Agreement and Second Amended and Restated Promissory Note in the amount of $50,000,000 with the Texas Capital Bank, which closed on August 31, 2012. The Amendment reflects the following changes: i) the liquidationreduction of the BP hedging instrument. The Credit Facility is secured by a lien on substantially all assets of the Company and its subsidiaries. The Credit Facility has a term of three years, and all principal amounts, together with all accrued and unpaidminimum interest will be due and payablerate to 3.75%, ii) an increase in full on July 3, 2011. The Credit Facility also provides for the issuance of letters-of-credit up to a $750,000 sub-limit under the borrowing base and up to an additional $2.25 million limit not subject to the borrowing base to support our hedging program. $7.0 million, iii) the addition of a provision resulting in an event of default if Robert G. Watson ceases to be the chief executive officer of any Borrower for any reason and a successor reasonably acceptable to Administrative Agent is not appointed within one hundred twenty (120) days thereafter, and iv) the addition of new leases to the collateral pool.
We had borrowings $7.328 million outstanding at March 31, 2009.
Our Current borrowing base utilized at the timeis $12.150 million, of the credit extensionon.which we had borrowed $8.5 million as of December 31, 2012. We may select Eurodollar loans of one, two, three and six months. A commitment fee of 0.375% on the unused portion of theintend to conduct an additional borrowing base will accrue, and be payable quarterly in arrears. There was no commitment fee due at March 31, 2009.
We financed the purchase of vehicles through a bank. The notes are for sevenfour years and the weighted average interest is 6.99%7.2% per annum. Vehicles collateralize these notes.
Long-term debt consistsat December 31, 2012 consisted of the following at March 31, 2009:
| Credit Facility | $ | 7,328,000 | ||
| Debentures | 2,700,000 | |||
| Unaccreted discount | (596,108 | ) | ||
| Debentures, net of unaccreted discount | 2,103,892 | |||
| Vehicle notes payable | 109,307 | |||
| Total long-term debt | 9,541,199 | |||
| Less current portion | (1,723,036 | ) | ||
| Long-term debt | $ | 7,818,163 |
Note 5 - Oil Properties
For the year ended March 31, 2009. In January 2009, Euramerica failed to fully fund both the balance of the purchase price and the remaining development capital owed under the agreements between us and Euramerica. Therefore, Euramerica has forfeited all of its interest in the property, including all interests in any wells, improvements or assets, and all of Euramerica's interest in the property reverts back to us. In addition, all operating agreements between us and Euramerica relating to the Gas City Project are null and void. We drilled 22 wells on behalf of Euramerica under the development agreement. We are currently exploring options to sell or further develop the Gas City Project through joint venture partnerships or other opportunities. The gas project remains shut in.
Note 6 - Related party transactions
In the normal course of business we utilize the services of stockholders who perform work for us at normal business rates.
Note 7 - Commitments and Contingencies
Rent expense for the years ended December 31, 2012, and 2011 were approximately $113,000 and $75,000 respectively. Future non-cancellable minimum lease payments are approximately $147,000 for 2013, $76,000 for 2014, $71,000 for 2015, $62,000 for 2016 and $63,000 for 2017. We received rental income form sub rentals of $50,000 in 2012 and will receive $37,000 in 2013.
We, as a lessee and operator of oil properties, are subject to various federal, state and local laws and regulations relating to discharge of materials into, and protection of, the environment. These laws and regulations may, among other things, impose liability on the lessee under an oil lease for the cost accounting requirements, the carrying value may not exceed an amount equalof pollution clean-up resulting from operations and subject to the sumlessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. As of December 31, 2012, we have no reserve for environmental remediation and are not aware of any environmental claims.
As of December 31, 2012, the Company has an outstanding irrevocable letter of credit in the amount of $25,000 issued in favor of the present valueTexas Railroad Commission. This letter of estimated future net revenues (adjusted for cash flow hedges) less estimated future expenditures to be incurredcredit is required by the Texas Railroad Commission by all companies operating in developing and producing the proved reserves, less any relatedstate of Texas with production greater than limits they prescribe.
Note 8 - Income Taxes
There was no current or deferred income tax effects. In calculating future net revenues, current prices and costs used are those as of the end of the appropriate quarterly period. Such prices are utilized except where different prices are fixed and determinable from applicable contracts for the remaining term of those contracts, including the effects of derivatives qualifying as cash flow hedges. A ceiling test charge occurs when the carrying value of the oil and gas properties exceeds the full cost ceiling.
The net deferred tax is as follows:
| March 31, 2009 | March 31, 2008 | |||||||
| Non-current deferred tax asset: | ||||||||
| Impaired oil & gas costs and long-lived assets | $ | 1,864,700 | $ | 312,800 | ||||
| Net operating loss carry-forward | 2,754,600 | 2,429,900 | ||||||
| Valuation allowance | (4,619,300 | ) | (2,742,700 | ) | ||||
| Total deferred tax net | $ | - | $ | - | ||||
| Year Ended December 31, | ||||||||
| 2012 | 2011 | |||||||
| Statutory tax rate | 34.0 | % | 34.0 | % | ||||
| Derivative instruments | (94.8 | )% | 7.8 | % | ||||
| Oil costs and long-lived assets | 30.7 | % | (0.3 | )% | ||||
| Non-deductible expenses | 14.9 | % | (5.1 | )% | ||||
| Change in valuation allowance | 15.2 | % | (36.4 | )% | ||||
| Effective tax rate | 0.0 | % | 0.0 | % | ||||
Significant components of the deferred tax assets and liabilities are as follows:
| Year Ended December 31, | ||||||||
| 2012 | 2011 | |||||||
| Non-current deferred tax asset: | ||||||||
| Oil costs and long-lived assets | $ | 698,339 | $ | 609,215 | ||||
| Derivative instruments | 612,139 | 927,333 | ||||||
| Net operating loss carry-forward | 8,010,770 | 7,960,080 | ||||||
| Valuation allowance | (9,321,248 | ) | (9,496,628 | ) | ||||
| $ | - | $ | - | |||||
At December 31, 2012, we have a net operating loss carry forward of approximately $23,549,000 expiring in 2021-2028 that is subject to certain limitations on an annual basis. A valuation allowance has been established against net operating losses where it is more likely than not that such losses will expire before they are utilized.
The Company incurred a change of control as defined by the Internal Revenue Code. Accordingly, the rules will limit the utilization of the Company’s net operating losses. The limitation is determined by multiplying the value of the stock immediately before the ownership change by the applicable long-term exempt rate. It is estimated that $10.2 million of net operating losses will be subject to an annual limitation. Any unused annual limitation may be carried over to later years. The amount of the limitation may under certain circumstances be increased by the built-in gains in assets held by the Company at the time of the change that are recognized in the five-year period after the change.
Note 9 - Fair Value Measurements
We hold certain financial assets which are required to be measured at fair value on a recurring basis in accordance with the Statement of Financial Accounting Standard No. 157, “Fair Value Measurements” (“ASC Topic 820-10”). ASC Topic 820-10 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for continuing operations isidentical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). ASC Topic 820-10 defines fair value as follows:
| March 31, 2009 | March 31, 2008 | |||||||
| Statutory tax rate | 34 | % | 34 | % | ||||
| Equity based compensation | (1 | )% | (15 | )% | ||||
| Oil & gas costs and long-lived assets | (29 | )% | 1 | % | ||||
| Change in valuation allowance | (4 | )% | (20 | )% | ||||
| Effective tax rate | 0 | % | 0 | % | ||||
Level 1. Valuations based on quoted prices in active markets for identical assets or liabilities that an entity has the ability to access. We believe receivables, payables and our debt approximate fair value at December 31, 2012.
Level 2. Valuations based on quoted prices for similar assets or liabilities, quoted prices for identical assets or liabilities in markets that are not active, or other inputs that are observable or can be corroborated by observable data for substantially the full term of the assets or liabilities. We consider the derivative liability to be Level 2. We determine the fair value of the derivative liability utilizing various inputs, including NYMEX price quotations and contract terms.
Level 3. Valuations based on inputs that are supported by little or no market activity and that are significant to the fair value of the assets or liabilities. We consider the marketable securities to be a Level 3. Our derivative instruments consist of fixed price commodity swaps.
| Fair Value Measurement | ||||||||||||
| Level 1 | Level 2 | Level 3 | ||||||||||
| Crude oil contracts | $ | - | $ | 1,800,295 | $ | - | ||||||
| Marketable securities | $ | - | $ | - | $ | 1,018,573 | ||||||
Note 10 – Subsequent Events
We have entered into certain derivative or physical arrangements with respect to portions of 2009, we retired $450,000our crude oil production to reduce our sensitivity to volatile commodity prices and/or to meet hedging requirements under our Credit Facility. We believe that these derivative arrangements, although not free of the $2.7 million Debentures that were outstanding at March 31, 2009, leaving a remaining balance of $2.25 million as of the date of this prospectus.
We have an Intercreditor Agreement in place between the Company; our counterparty, BP Corporation North America, Inc. (“BP”); and our agent, Texas Capital Bank, N.A., which allows Texas Capital Bank to also act as agent for BP for the purpose of holding and enforcing any liens or payment-in-kind interest (an increasesecurity interests resulting from our derivative arrangements. Therefore, we generally are not required to post additional collateral, including cash.
The following derivative contracts were in place at December 31, 2012:
| Term | Monthly Volumes | Price/Bbl | Fair Value | |||||||||||
| Crude oil swap | 1/13-12/14 | 1,933 Bbls | $ | 76.74 | $ | (1,077,333 | ) | |||||||
| Crude oil swap | 7/11-12/15 | 2,517 Bbls | $ | 83.70 | (722,962 | ) | ||||||||
| $ | (1,800,295 | ) | ||||||||||||
Monthly volume is the weighted average throughout the period.
The total fair value is shown as a derivative instrument in both the current and non-current liabilities on the balance sheet. We recorded losses on the derivative contracts for the years ended December 31, 2012, and 2011 of $871,331 and $409,399 respectively.
Note 11 - Income (Loss) Per Common Share
The Company reports earnings (loss) per share in accordance with ASC Topic 260-10, "Earnings per Share." Basic earnings (loss) per share is computed by dividing income (loss) available to common shareholders by the weighted average number of common shares available. Diluted earnings (loss) per share is computed similar to basic earnings (loss) per share except that the denominator is increased to include the number of additional common shares that would have been outstanding if the potential common shares had been issued and if the additional common shares were dilutive.
Potential common shares as of December 31, 2012, include 250,000 warrants, 1,685,000 stock options, and 4,779,460 shares from the conversion of preferred shares. Potential common shares as of December 31, 2011, include 2,838,330 warrants, 900,000 stock options and 4,779,460 from the conversion of preferred shares.
Note 12 - Accounts Payable
The Company's current liabilities at December 31, 2012, and 2011 include accounts payable in the amount of principal due) or payment-in-kind shares (issuance$2,384,090 and $2,355,692 respectively. Accounts payable for 2012 and 2011 included $492,134 payable to former attorneys of the Company that are in dispute.
Note 13 - Note Payable
On November 30, 2012, the Company purchased two million shares of common stock),stock from a shareholder of the Company for $323,035 in cash (including an option payment that we previously made to the selling stakeholder) and add a provisionnote payable of $825,000 bearing interest at a rate per annum of twenty-four hundredths percent (0.24%). Principal and accrued interest are payable as follows:
On or before March 31, 2013, $200,000.00 plus accrued interest.
On or before June 30, 2013, $200,000.00 plus accrued interest.
On or before September 30, 2013, $200,000.00 plus accrued interest.
On or before December 31, 2013, $225,000.00 plus accrued interest.
Note 14 - Subsequent Events
In January 2013, the Company issued an advisor warrants for the conversionpurchase of 300,000 shares of the debentures intoCompany’s common stock with a strike price equal to $0.70 per share for investor relation services, and the Company issued 130,000 shares of EnerJex’s common stock. See stock and 35,000 options to employees.
Note 5.
Results of operations from oil and natural gas producing activities
The following table shows the results of operations from the Company’s oil and gas producing activities. Results of operations from these activities are determined using historical revenues, production costs and depreciation depletion and amortizationdepletion. The results of operations from the capitalized costs subject to amortization. GeneralCompany’s oil producing activities below exclude non-oil revenues, general and administrative expenses, professional, investor relationsinterest income and interest expense. Income tax expense is excluded from this determination.
| March 31, 2009 | March 31, 2008 | |||||||
| Production revenues | $ | 6,436,805 | $ | 3,602,798 | ||||
| Production costs | (2,637,333 | ) | (1,795,188 | ) | ||||
| Depletion and depreciation | (892,871 | ) | (913,224 | ) | ||||
| Results of operations for producing activities | $ | 2,906,601 | $ | 894,386 | ||||
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | |||||||
| Production revenues | $ | 8,496,519 | $ | 6,285,411 | ||||
| Production costs | (3,102,321 | ) | (3,440,228 | ) | ||||
| Depletion and depreciation | (1,541,069 | ) | (1,128,712 | ) | ||||
| Income tax | (1,305,513 | ) | (583,600 | ) | ||||
| Results of operations for producing activities | $ | 2,547,616 | $ | 1,132,871 | ||||
Capitalized costs
The following table summarizes the Company’s capitalized costs of oil and natural gas producing properties
| March 31, 2009 | March 31, 2008 | |||||||
| Proved | $ | 8,566,979 | $ | 10,207,596 | ||||
| Unevaluated and unproved | 31,183 | 62,216 | ||||||
| Accumulated depreciation and depletion | (1,817,956 | ) | (925,086 | ) | ||||
| Sale of properties | (300,000 | ) | (300,000 | ) | ||||
| Net capitalized costs | $ | 6,480,206 | $ | 9,044,726 | ||||
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | |||||||
| Unevaluated properties not subject to amortization | $ | 7,830,828 | $ | 7,922,734 | ||||
| Properties subject to amortization | 30,466,951 | 21,602,640 | ||||||
| Capitalized costs | 38,297,779 | 29,525,374 | ||||||
| Accumulated depletion | (5,094,881 | ) | (3,764,874 | ) | ||||
| Net capitalized costs | $ | 33,202,898 | $ | 25,760,500 | ||||
Cost incurred in oil and natural gas property acquisition, exploration and development activities that have been capitalized are summarized below:
| March 31, 2009 | March 31, 2008 | |||||||
| Acquisition of proved and unproved properties | $ | 123,040 | $ | 4,352,040 | ||||
| Development costs | 2,999,963 | 5,178,281 | ||||||
| Exploration costs | - | - | ||||||
| Total | $ | 3,123,003 | $ | 9,530,321 | ||||
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | |||||||
| Acquisition of properties | $ | - | $ | 1,422,590 | ||||
| Exploration costs | - | - | ||||||
| Development costs | 10,247,539 | 4,926,105 | ||||||
| Net capitalized costs | $ | 10,247,539 | $ | 6,348,695 | ||||
Estimated quantities of proved reserves
Our ownership interests in estimated quantities of proved oil and gas reserves and changes in net proved reserves all of which are located in the United States are summarized below. Proved reserves are estimated quantities of natural gas and oil that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are those that are expected to be recovered through existing wells with existing equipment and operating methods. Reserves are stated in thousand cubic feet (mcf) of natural gas and barrels (stb) of oil. Geological and engineering estimates by MHA Petroleum Consultants, LLC of proved natural gas and oil reserves at one point in time are highly interpretive, inherently imprecise and subject to ongoing revisions that may be substantial in amount. Although every reasonable effort is made to ensure that the reserve estimates are accurate, by their nature reserve estimates are generally less precise than other estimates presented in connection with financial statement disclosures.
| March 31, 2009 | March 31, 2008 | |||||||||||||||
| Gas-mcf | Oil-stb | Gas-mcf | Oil-stb | |||||||||||||
| Proved reserves: | ||||||||||||||||
| Revisions of previous estimates | (394,732 | ) | (14,575 | ) | - | - | ||||||||||
| Purchase of minerals in place | - | 53,280 | 418,959 | 347,228 | ||||||||||||
| Extensions and discoveries | - | - | 1,068,683 | |||||||||||||
| Production | (6,465 | ) | (74,289 | ) | (17,762 | ) | (43,697 | ) | ||||||||
| Total | - | 1,336,630 | 401,197 | 1,372,214 | ||||||||||||
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | |||||||
| Oil-stb | Oil-stb | |||||||
| Proved reserves: | ||||||||
| Beginning | 2,714,150 | 2,320,150 | ||||||
| Revisions of previous estimates | (193,059 | ) | (130,908 | ) | ||||
| Purchase of minerals in place | - | 700,190 | ||||||
| Extension and discoveries | 502,751 | 316,049 | ||||||
| Sale of minerals in place | - | (221,365 | ) | |||||
| Sales of Rantoul Partners interest | (198,187 | ) | ||||||
| Production | (96,842 | ) | (71,729 | ) | ||||
| Ending | 2,927,000 | 2,714,200 | ||||||
Proved developed reserves for December 31, 2012, and 2011 consisted of 100% oil and totaled 1,546.3 and 643.1 MBbls, respectively. Proved undeveloped reserves at the end of the period:
| Gas- mcf | Oil – stb | |||
| March 31, 2009 | March 31, 2009 | |||
| - | 524,980 | |||
| Gas- mcf | Oil stb | |||
| March 31, 2008 | March 31, 2008 | |||
| 401,197 | 861,240 | |||
Standardized measure of discounted future net cash flows
The standardized measure of discounted future net cash flows from our proved reserves for the periods presented in the financial statements is summarized below. The standardized measure of future cash flows as of March 31, 2009 and 2008 is calculated using a price per Mcf of gas of $0 and $7.479, respectively and a price for oil of $42.65 and $94.53, respectively. The resulting estimated future cash inflows are reduced by estimated future costs to develop and produce the estimated proved reserves. These costs are based on year-end cost levels. Future income taxes are based on year-end statutory rates. The future net cash flows are reduced to present value by applying a 10% discount rate. The standardized measure of discounted future cash flows is not intended to represent the replacement cost or fair market value of the Company’s oil and gas properties.
March 31, 2009 | March 31, 2008 | |||||||
| Future production revenue | $ | 57,007,970 | $ | 132,457,459 | ||||
| Future production costs | (24,732,440 | ) | (39,629,625 | ) | ||||
| Future development costs | (9,584,500 | ) | (18,827,013 | ) | ||||
| Future cash flows before income taxes | 22,691,030 | 74,000,821 | ||||||
| Future income taxes | - | (19,241,954 | ) | |||||
| Future net cash flows | 22,691,030 | 54,758,867 | ||||||
| 10% annual discount for estimating of future cash flows | (12,061,690 | ) | (26,558,364 | ) | ||||
| Standardized measure of discounted net cash flows | $ | 10,629,340 | $ | 28,200,503 | ||||
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | |||||||
| Future production revenue | $ | 246,535,000 | $ | 242,383,840 | ||||
| Future production costs | (69,131,000 | ) | (93,373,850 | ) | ||||
| Future development costs | (11,766,000 | ) | (12,767,540 | ) | ||||
| Future cash flows before income tax | 165,638,000 | 136,242,450 | ||||||
| Future income taxes | (33,550,000 | ) | (22,864,737 | ) | ||||
| Future net cash flows | 132,088,000 | 113,377,713 | ||||||
| 10% annual discount for estimating of future cash flows | (83,215,000 | ) | (69,730,808 | ) | ||||
| Standardized measure of discounted net cash flows | $ | 48,873,000 | $ | 43,646,905 | ||||
Changes in Standardized Measure of Discounted Future Net Cash Flows
The following is a summary of a Standardized Measure of discounted net future cash flows related to the Company’s proved oil reserves. The information presented is based on a calculation of estimated proved reserves using discounted cash flows based on the 12-month average price for oil calculated as the unweighted arithmetic average of the first-day-of-the-month price for each month within the 12-month prior period. The additions to estimated proved reserves from new discoveries and extensions could vary significantly from year to year. Additionally, the impact of changes to reflect current prices and costs of reserves proved in prior years could also be significant.
| Year Ended December 31, 2012 | Year Ended December 31, 2011 | |||||||
| Balance beginning of year | $ | 43,646,905 | $ | 25,304,892 | ||||
| Sales, net of production costs | (5,394,198 | ) | (2,869,339 | ) | ||||
| Net change in pricing and production costs | 2,870,156 | 11,287,884 | ||||||
| Net change in future estimated development costs | (1,001,445 | ) | (702,640 | ) | ||||
| Purchase of minerals in place | - | 16,834,878 | ||||||
| Extensions and discoveries | 11,274,543 | 7,598,861 | ||||||
| Sale of minerals in place | - | (5,322,346 | ) | |||||
| Sale of Rantoul Partners interest | - | (4,765,069 | ) | |||||
| Revisions | (4,329,483 | ) | (3,147,460 | ) | ||||
| Accretion of discount | 5,324,900 | 3,119,577 | ||||||
| Change in income tax | (3,518,817 | ) | (3,692,333 | ) | ||||
| Balance end of year | $ | 48,872,560 | $ | 43,646,905 | ||||
| March 31, 2009 | March 31, 2008 | |||||||
| Balance beginning of year | $ | 28,200,503 | $ | - | ||||
| Sales, net of production costs | (5,697,410 | ) | (1,777,278 | ) | ||||
| Net change in pricing and production costs | (31,927,063 | ) | - | |||||
| Net change in future estimated development costs | 9,220,510 | - | ||||||
| Purchase of minerals in place | 136,190 | 8,124,394 | ||||||
| Extensions and discoveries | 518,297 | 21,853,387 | ||||||
| Revisions | (1,089,039 | ) | - | |||||
| Accretion of discount | (143,477 | ) | - | |||||
| Change in income tax | 11,410,829 | - | ||||||
| Balance end of year | $ | 10,629,340 | $ | 28,200,503 | ||||
Unaudited
| September 30, | December 31, | ||||||
| 2013 | 2012 | ||||||
| Assets | |||||||
| Current assets: | |||||||
| Cash and cash equivalents | $ | 990,991 | $ | 767,494 | |||
| Restricted cash | 228,840 | - | |||||
| Accounts receivable | 2,237,819 | 1,221,962 | |||||
| Inventory | 443,070 | - | |||||
| Marketable securities | 1,018,573 | 1,018,573 | |||||
| Deposits and prepaid expenses | 818,466 | 528,468 | |||||
| Total current assets | 5,737,759 | 3,536,497 | |||||
| Non-current assets: | |||||||
| Fixed assets, net of accumulated depreciation | 2,412,446 | 309,877 | |||||
| Oil properties using full-cost accounting, net of accumulated DD&A | 59,295,171 | 33,202,898 | |||||
| Other non-current assets | 817,506 | - | |||||
| Total non-current assets | 62,525,123 | 33,512,775 | |||||
| Total assets | $ | 68,262,882 | $ | 37,049,272 | |||
| Liabilities and Stockholders' Equity | |||||||
| Current liabilities: | |||||||
| Accounts payable | $ | 2,867,478 | $ | 2,384,090 | |||
| Accrued liabilities | 2,768,750 | 590,205 | |||||
| Derivative liability | 1,335,041 | 757,181 | |||||
| Note payable | 225,000 | 825,000 | |||||
| Total current liabilities | 7,196,269 | 4,556,476 | |||||
| Asset retirement obligation | 2,626,043 | 1,336,151 | |||||
| Long-term debt | 29,556,351 | 8,500,000 | |||||
| Derivative liability | 533,002 | 1,043,114 | |||||
| Total non-current liabilities | 32,715,396 | 10,879,265 | |||||
| Total liabilities | 39,911,665 | 15,435,741 | |||||
| Commitments & Contingencies | |||||||
| Stockholders' Equity: | |||||||
| Preferred stock, $0.001 par value, 25,000,000 shares authorized, 4,779,460 shares issued and outstanding | 4,780 | 4,780 | |||||
| Common stock, $0.001 par value, 250,000,000 shares authorized; shares issued and outstanding 115,005,443 at September 30, 2013 and 73,586,529 at December 31, 2012 | 115,005 | 73,587 | |||||
| Treasury Stock, 5,750,000 shares | (2,551,000) | (2,551,000) | |||||
| Paid-in capital | 52,514,870 | 45,352,096 | |||||
| Accumulated other comprehensive income | (552,589) | (552,589) | |||||
| Retained (deficit) | (21,179,849) | (20,713,343) | |||||
| Total stockholders' equity | 28,351,217 | 21,613,531 | |||||
| Total liabilities and stockholders' equity | $ | 68,262,882 | $ | 37,049,272 | |||
| September 30, | March 31, | |||||||
| 2009 | 2009 | |||||||
| (Unaudited) | (Audited) | |||||||
| Assets | ||||||||
| Current assets: | ||||||||
| Cash | $ | 89,546 | $ | 127,585 | ||||
| Accounts receivable | 490,599 | 462,044 | ||||||
| Prepaid debt issue costs | 22,902 | 45,929 | ||||||
| Deferred and prepaid expenses | 222,876 | 263,383 | ||||||
| Total current assets | 825,923 | 898,941 | ||||||
| Fixed assets | 431,600 | 365,019 | ||||||
| Less: Accumulated depreciation | 108,354 | 63,988 | ||||||
| Total fixed assets | 323,246 | 301,031 | ||||||
| Other assets: | ||||||||
| Oil and gas properties using full-cost accounting: | ||||||||
| Properties not subject to amortization | 6,351 | 31,183 | ||||||
| Properties subject to amortization | 6,177,631 | 6,449,023 | ||||||
| Total other assets | 6,183,982 | 6,480,206 | ||||||
| Total assets | $ | 7,333,151 | $ | 7,680,178 | ||||
| Liabilities and Stockholders’ Equity (Deficit) | ||||||||
| Current liabilities: | ||||||||
| Accounts payable | $ | 677,916 | $ | 1,016,168 | ||||
| Accrued liabilities | 79 | 87,811 | ||||||
| Deferred payments – development | 148,125 | - | ||||||
| Long-term debt, current | 332,466 | 1,723,036 | ||||||
| Total current liabilities | 1,158,586 | 2,827,015 | ||||||
| Asset retirement obligation | 845,301 | 803,624 | ||||||
| Convertible note payable | 25,000 | 25,000 | ||||||
| Long-term debt, net of discount of $316,618 and $596,108 | 8,696,029 | 7,818,163 | ||||||
| Total liabilities | 10,724,916 | 11,473,802 | ||||||
| Commitments and contingencies | ||||||||
| Stockholders’ Equity (Deficit): | ||||||||
| Preferred stock, $0.001 par value, 10,000,000 shares authorized, no shares issued and outstanding | - | - | ||||||
| Common stock, $0.001 par value, 100,000,000 shares authorized; shares issued and outstanding – 4,799,236 at September 30, 2009 and 4,443,512 at March 31, 2009 | 4,799 | 4,444 | ||||||
| Common stock owed but not issued | 153 | - | ||||||
| Paid-in capital | 9,434,516 | 8,932,906 | ||||||
| Retained (deficit) | (12,831,233 | ) | (12,730,974 | ) | ||||
| Total stockholders’ equity (deficit) | (3,391,765 | ) | (3,793,624 | ) | ||||
| Total liabilities and stockholders’ equity | $ | 7,333,151 | $ | 7,680,178 | ||||
| F-47 |
| For the Three Months Ended | For the Nine Months Ended | ||||||||||||
| September 30, | September 30, | ||||||||||||
| 2013 | 2012 | 2013 | 2012 | ||||||||||
| Oil revenues | $ | 2,694,506 | $ | 2,252,681 | $ | 7,228,543 | $ | 6,204,738 | |||||
| Expenses: | |||||||||||||
| Direct operating costs | 916,567 | 807,887 | 2,450,596 | 2,162,470 | |||||||||
| Depreciation, depletion and amortization | 484,478 | 459,815 | 1,347,576 | 1,290,334 | |||||||||
| Professional fees | 264,050 | 364,519 | 889,529 | 1,037,248 | |||||||||
| Salaries | 138,875 | 112,370 | 570,864 | 355,750 | |||||||||
| Administrative expense | 220,693 | 152,117 | 534,340 | 598,043 | |||||||||
| Total expenses | 2,024,663 | 1,896,708 | 5,792,905 | 5,443,845 | |||||||||
| Income (loss) from operations | $ | 669,843 | $ | 355,973 | $ | 1,435,638 | $ | 760,893 | |||||
| Other income (expense): | |||||||||||||
| Interest expense | (137,831) | (120,922) | (393,204) | (258,529) | |||||||||
| Gain (loss) on derivatives | (1,160,374) | (1,529,127) | (992,556) | 161,353 | |||||||||
| Other income (loss) | 8,460 | (1,973) | 66,841 | 20,278 | |||||||||
| Total other income (expense) | (1,289,745) | (1,652,022) | (1,318,919) | (76,898) | |||||||||
| Net income (loss) | $ | (619,902) | $ | (1,296,049) | $ | 116,719 | $ | 683,995 | |||||
| Net income (loss) attributed to EnerJex Resources, Inc. | (619,902) | (1,422,880) | 116,719 | 411,801 | |||||||||
| Net income attributed to non-controlling interest in subsidiary | - | 126,831 | - | 272,194 | |||||||||
| Net income (loss) | $ | (619,902) | $ | (1,296,049) | $ | 116,719 | $ | 683,995 | |||||
| Net income (loss) per share | $ | (0.01) | $ | (0.02) | $ | 0.00 | $ | 0.01 | |||||
| Weighted average shares | 68,375,756 | 69,714,165 | 68,018,247 | 69,770,308 | |||||||||
| Diluted earnings per share | $ | (0.01) | $ | (0.02) | $ | 0.00 | $ | 0.01 | |||||
| Weighted average shares-diluted | 73,434,527 | 69,714,165 | 73,077,017 | 71,295,730 | |||||||||
| For the Three Months Ended | For the Six Months Ended | |||||||||||||||
| September 30, | September 30, | |||||||||||||||
| 2009 | 2008 | 2009 | 2008 | |||||||||||||
| Oil and natural gas revenues | $ | 1,394,117 | $ | 1,777,656 | $ | 2,789,179 | $ | 3,467,742 | ||||||||
| Expenses: | ||||||||||||||||
| Direct operating costs | 430,316 | 816,767 | 864,835 | 1,531,300 | ||||||||||||
| Depreciation, depletion and amortization | 289,604 | 347,859 | 445,895 | 718,048 | ||||||||||||
| Professional fees | 310,455 | 171,083 | 419,139 | 294,785 | ||||||||||||
| Salaries | 399,254 | 276,939 | 552,989 | 494,426 | ||||||||||||
| Administrative expense | 264,714 | 557,664 | 455,316 | 836,430 | ||||||||||||
| Total expenses | 1,694,343 | 2,170,312 | 2,738,174 | 3,874,989 | ||||||||||||
| Income (loss) from operations | (300,226 | ) | (392,656 | ) | 51,005 | (407,247 | ) | |||||||||
| Other income (expense): | ||||||||||||||||
| Interest expense | (174,727 | ) | (258,237 | ) | (353,565 | ) | (532,624 | ) | ||||||||
| Loan interest accretion | (144,101 | ) | (2,224,554 | ) | (279,490 | ) | (2,567,379 | ) | ||||||||
| Management fee revenue | 75,291 | - | 75,291 | - | ||||||||||||
| Gain on repurchase of debentures | - | - | 406,500 | - | ||||||||||||
| Total other income (expense) | (243,537 | ) | (2,482,791 | ) | (151,264 | ) | (3,100,003 | ) | ||||||||
| Net income (loss) | $ | (543,763 | ) | $ | (2,875,447 | ) | $ | (100,259 | ) | $ | (3,507,250 | ) | ||||
| Weighted average shares outstanding | ||||||||||||||||
| Common shares outstanding basic and diluted | 4,670,767 | 4,443,467 | 4,557,760 | 4,442,930 | ||||||||||||
| Net income (loss) per share - basic | $ | (0.12 | ) | $ | (0.65 | ) | $ | (0.02 | ) | $ | (0.79 | ) | ||||
| F-48 |
| For the Nine Months Ended | |||||||
| September 30, | |||||||
| 2013 | 2012 | ||||||
| Cash flows from operating activities | |||||||
| Net income (loss) | $ | 116,719 | $ | 683,995 | |||
| Depreciation and depletion | 1,347,576 | 1,290,334 | |||||
| Stock, options and warrants issued for services | 162,021 | 154,074 | |||||
| Accretion of asset retirement obligation | 84,578 | 75,551 | |||||
| Settlements of asset retirement obligations | (36,758) | - | |||||
| (Gain) loss on derivatives | 67,748 | (903,178) | |||||
| Loss on sale of fixed assets | 7,785 | 308 | |||||
| Changes in assets and liabilities: | |||||||
| Accounts receivable | (137,386) | 164,170 | |||||
| Inventory | (169,940) | - | |||||
| Deposits and prepaid expenses | (187,477) | (111,797) | |||||
| Accounts payable | (101,643) | (792,513) | |||||
| Accrued liabilities | 650,172 | 275,993 | |||||
| Cash flows from operating activities | 1,803,395 | 836,937 | |||||
| Cash flows from investing activities | |||||||
| Settlements of asset retirement obligations | (18,910) | - | |||||
| Purchase of fixed assets | (103,874) | (58,818) | |||||
| Additions to oil and gas properties | (4,962,813) | (6,414,494) | |||||
| Proceeds from sale of oil and gas properties | 454,973 | - | |||||
| Proceeds from sale of fixed assets | 1,600 | 8,562 | |||||
| Net cash acquired from Black Raven | 656,693 | - | |||||
| Cash flows used in investing activities | (3,972,331) | (6,464,750) | |||||
| Cash flows from financing activities | |||||||
| Payments on long-term debt | - | (17,484) | |||||
| Payments on note payable | (600,000) | - | |||||
| Deferred financing costs | (211,584) | - | |||||
| Proceeds from borrowings | 4,000,000 | 1,850,000 | |||||
| Distribution to non-controlling interest in subsidiary | - | (353,162) | |||||
| Sale of non-controlling interest in subsidiary | - | 2,000,000 | |||||
| Dividends paid on preferred stock | (567,143) | (215,694) | |||||
| Cash flows from financing activities | 2,621,273 | 3,263,660 | |||||
| Net increase (decrease) in cash | 452,337 | (2,364,153) | |||||
| Cash – beginning | 767,494 | 2,770,440 | |||||
| Cash – ending | $ | 1,219,831 | $ | 406,287 | |||
| Supplemental disclosures: | |||||||
| Interest paid | $ | 212,751 | $ | 182,978 | |||
| Non-cash transactions: | |||||||
| Share based payments issued for services | $ | 162,021 | $ | 154,074 | |||
| For the Six Months Ended | ||||||||
| September 30, | ||||||||
| 2009 | 2008 | |||||||
| Cash flows (used in) / provided from operating activities | ||||||||
| Net income (loss) | $ | (100,259 | ) | $ | (3,507,250 | ) | ||
| Depreciation and depletion | 460,974 | 741,311 | ||||||
| Amortization of stock and options for services | - | 79,455 | ||||||
| Accretion of interest on long-term debt discount | 279,490 | 2,567,379 | ||||||
| Principal increase on debentures | 214,707 | - | ||||||
| Shares issued for interest on debentures | 5,368 | - | ||||||
| Shares issued for compensation and services | 494,750 | - | ||||||
| Accretion of asset retirement obligation | 37,396 | 31,741 | ||||||
| Adjustments to reconcile net income (loss) to cash used in operating activities: | ||||||||
| Accounts receivable | (28,555 | ) | (601,677 | ) | ||||
| Prepaid expenses | 63,533 | (671,006 | ) | |||||
| Accounts payable | (338,252 | ) | 1,309,643 | |||||
| Accrued liabilities | (87,732 | ) | (54,195 | ) | ||||
| Deferred payment - development | 148,125 | (251,951 | ) | |||||
| Net cash (used in) / provided from operating activities | 1,149,545 | (356,550 | ) | |||||
| Cash flows (used in) / provided from investing activities | ||||||||
| Purchase of fixed assets | (63,180 | ) | (167,184 | ) | ||||
| Additions to oil & gas properties | (117,504 | ) | (2,114,515 | ) | ||||
| Net cash (used in) / provided from investing activities | (180,684 | ) | (2,281,699 | ) | ||||
| Cash flows (used in) / provided from financing activities | ||||||||
| Payments on long-term debt | (1,045,380 | ) | (8,357,227 | ) | ||||
| Borrowings on long-term debt | 38,480 | 11,273,442 | ||||||
| Notes payable, net | - | (965,000 | ) | |||||
| Net cash (used in) / provided from financing activities | (1,006,900 | ) | 1,951,215 | |||||
| Net increase (decrease) in cash | (38,039 | ) | (687,034 | ) | ||||
| Cash - beginning | 127,585 | 951,004 | ||||||
| Cash - ending | $ | 89,546 | $ | 263,970 | ||||
| Supplemental disclosures: | ||||||||
| Interest paid | $ | 151,334 | $ | 505,617 | ||||
| Income taxes paid | $ | - | $ | - | ||||
| Non-cash transactions: | ||||||||
| Shares issued for interest on debentures | $ | 5,368 | $ | - | ||||
| Shares issued for compensation and services | $ | 494,750 | $ | - | ||||
| Share-based payments issued for services | $ | - | $ | 79,455 | ||||
| Asset retirement obligation | $ | 4,281 | $ | 246,871 | ||||
| F-49 |
| Options | Weighted Avg. Exercise Price | Warrants | Weighted Avg. Exercise Price | ||||||||
| Outstanding December 31, 2012 | 1,685,000 | $ | 0.54 | 250,000 | $ | 0.70 | |||||
| Granted | 37,000 | 0.70 | 300,000 | 0.70 | |||||||
| Cancelled | 5,000 | 0.70 | 550,000 | 0.70 | |||||||
| Exercised | - | - | - | - | |||||||
| Outstanding September 30, 2013 | 1,717,000 | $ | 0.54 | - | $ | - | |||||
| Options | Weighted Ave. Exercise Price | Warrants | Weighted Ave. Exercise Price | |||||||||||||
| Outstanding March 31, 2009 | 438,500 | $ | 6.30 | 75,000 | $ | 3.00 | ||||||||||
| Cancelled | (438,500 | ) | (6.30 | ) | - | - | ||||||||||
| Exercised | - | - | - | - | ||||||||||||
| Outstanding September 30, 2009 | - | $ | - | 75,000 | $ | 3.00 | ||||||||||
| Fair Value Measurement | ||||||||||
| Level 1 | Level 2 | Level 3 | ||||||||
| Crude oil contracts | $ | - | $ | (1,868,043) | $ | - | ||||
| Marketable Securities | $ | - | $ | - | $ | 1,018,573 | ||||
| Asset retirement obligation, April 1, 2009 | $ | 803,624 | ||
| Liabilities incurred during the period | 4,281 | |||
| Liabilities settled during the period | - | |||
| Accretion | 37,396 | |||
| Asset retirement obligations, September 30, 2009 | $ | 845,301 |
| Asset retirement obligations, December 31, 2012 | $ | 1,336,151 | ||
| Liabilities incurred during the period | 50,269 | |||
| Liabilities settled during the period | (96,466) | |||
| Liabilities of Black Raven acquired September 27, 2013 | 1,251,511 | |||
| Accretion | 84,578 | |||
| Asset retirement obligations, September 30, 2013 | $ | 2,626,043 |
| Term | Monthly Volumes | Price/Bbl | Fair Value | ||||||||
| Crude oil swap | 10/13-12/15 | 1,711Bbls | $ | 76.74 | (871,272) | ||||||
| Crude oil swap | 10/13-12/15 | 2,589Bbls | 83.70 | (670,495) | |||||||
| Crude oil collar | 10/13-12/13 | 1,587Bbls | 90.00-94.50 | (40,453) | |||||||
| Crude oil swap | 1/14-12/14 | 1,369Bbls | 90.25 | (99,975) | |||||||
| Crude oil swap | 10/13-12/13 | 1,300Bbls | 97.10 | (22,880) | |||||||
| Crude oil swap | 1/14-12/14 | 1,900Bbls | 96.00 | (8,170) | |||||||
| Crude oil swap | 1/15-12/15 | 5,800Bbls | 88.55 | (40,948) | |||||||
| Crude oil swap | 10/13-12/14 | 3,000Bbls | 95.15 | (113,850) | |||||||
| $ | (1,868,043) | ||||||||||
| F-52 |
| F-53 |
| Credit Facility | $ | 6,746,000 | ||
| Debentures | 2,464,707 | |||
| Unaccreted discount | (316,618 | ) | ||
| Debentures, net of unaccreted discount | 2,148,089 | |||
| Vehicle notes payable | 134,406 | |||
| Total long-term debt | 9,028,495 | |||
| Less current portion | 332,466 | |||
| Long-term debt | $ | 8,696,029 |
For the Three Months Ended September 30,
| 2013 | 2012 | ||||||
| Revenues | $ | 3,831,903 | $ | 3,411,772 | |||
| Income from operations | $ | 491,551 | $ | 440,049 | |||
| Net (loss) | $ | (1,392,633) | $ | (1,335,905) | |||
| Net (loss) per share | $ | (.02) | $ | (.02) | |||
We have reviewed all material events through the date of this report in accordance with ASC 855-10.The final determination of cash elected by Black Raven common shareholders was made on November 12, 2013 and $207,067 was paid to the former Black Raven shareholders for their common stock.
PART II
INFORMATION NOT REQUIRED IN PROSPECTUS
Item 13. Other Expenses of Issuance and Distribution
The following table sets forth all coststhe various expenses (other than discounts, commissions, and expenses, other than underwriting discounts and commissions,fees of underwriters, selling brokers, dealer managers or similar securities industry professionals ) to be paidincurred in connection with the saleoffering of the common stocksecurities being registered hereunder,hereby, all of which will be paidborne by us.the Company. All of the amounts shown are estimatesestimated except for the Securities and Exchange CommissionSEC registration fee.
| SEC registration fee | $ | 46.54 | ||
| Legal fees and expenses | 20,000 | |||
| Accounting fees and expenses | 1,500 | |||
| Miscellaneous fees and expenses | 453.46 | |||
| Total | $ | 22,000 |
| SEC registration fee | $ | 1,031 | ||||
| FINRA filing fees | $ | * | ||||
| Printing expenses | $ | * | ||||
| Legal fees and expenses | $ | * | ||||
| Underwriting Fees | $ | * | ||||
| Accounting fees and expenses | $ | * | ||||
| Total | $ | * |
* to be included in amendment
Item 14. Indemnification of Directors and Officers
Section 78.7502(1) of the Nevada Revised Statutes (iv)("NRS") authorizes a Nevada corporation to indemnify any director, officer, employee, or corporate agent "who was or is a party or is threatened to be made a party to any threatened, pending or completed action, suit or proceeding, whether civil, criminal, administrative or investigative, except an action by or in the payment of dividends in violation of Section 78.300right of the Nevada Revised Statutes or, (v) for any transaction from which the director derived an improper personal benefit.
Section 78.7502(2) of the NRS also authorizes indemnification of the reasonable defense or settlement expenses of a corporate director, officer, employee or agent who is sued, or is threatened with a suit, by or in the right of the corporation. The Bylaws, therefore, limit the liability of directors to the maximum extent permitted by Nevada law (Section 78.751).
To the extent that a stockholder believescorporate director, officer, employee, or agent is successful on the officers and/merits or directors have violated their fiduciary duties to us, the stockholder may, subject to applicable rules of civil procedure, be able to bring a classotherwise in defending any action or derivative suitproceeding referred to enforcein Section 78.7502(1) or 78.7502(2), Section 78.7502(3) of the stockholder’s rights,NRS requires that he be indemnified "against expenses, including rights under certain federalattorneys' fees, actually and state securities laws and regulations to recover damages from and require an accountingreasonably incurred by management. Stockholders who have suffered losseshim in connection with the purchasedefense."
Unless ordered by a court or sale of their interest in EnerJex Resources, Inc. in connection with such sale or purchase, including the misapplication by any such officer or directoradvanced pursuant to Section 78.751(2), Section 78.751(1) of the proceeds fromNRS limits indemnification under Section 78.7502 to situations in which either (1) the salestockholders, (2) the majority of these securities, may be able to recover such losses from us.
Section 78.751(2) authorizes a corporation's articles of our executive officers (the “Indemnification Agreements”). The Indemnification Agreementsincorporation, bylaws or agreement to provide that we will indemnify each suchdirectors’ and officers’ expenses incurred in defending a civil or criminal action must be paid by the corporation as incurred, rather than upon final disposition of the action, upon receipt by the director or executive officer to repay the fullest extent permitted by Nevada lawamount if a court ultimately determines that he is not entitled to indemnification.
Section 78.751(3)(a) provides that the rights to indemnification and advancement of expenses shall not be deemed exclusive of any other rights under any bylaw, agreement, stockholder vote or she becomesvote of disinterested directors. Section 78.751(3) (b) extends the rights to indemnification and advancement of expenses to former directors, officers, employees and agents, as well as their heirs, executors, and administrators.
Regardless of whether a partydirector, officer, employee or agent has the right to or is threatened with any action, suit or proceeding arising out ofindemnity, Section 78.752 allows the corporation to purchase and maintain insurance on his behalf against liability resulting from his or her servicecorporate role.
At present, there is no pending litigation or proceeding involving any director, officer, employee or agent as a directorto which indemnification will be required or executive officer.permitted under the Certificate. The Indemnification Agreements also provide that we will advance, if requested by an indemnified person, any and all expenses incurred in connection with any such proceeding, subject to reimbursement by the indemnified person should a final judicial determination be made that indemnificationRegistrant is not available under applicable law. The Indemnification Agreements further provideaware of any threatened litigation or other proceeding that if we maintain directors’ and officers’ liability coverage, each indemnified person shall be includedmay result in a claim for such coverage to the maximum extent of the coverage available for our directors or executive officers.
Item 15. Recent Sales of Unregistered Securities
On November 20, 2013, we issued 71,429 shares of Common Stock with a fair value of approximately $37,143 to a vendor’s designee in consideration for public relations services pursuant to an exemption from registration under Regulation D.
Item 16. Exhibits and Financial Statement Schedules.
The following is a summarylist of transactions by us from March 31, 2006 throughexhibits in the date ofIndex to Exhibits to this registration statement involvingstatements is incorporated herein by reference.
Item 17. Undertakings.
The undersigned registrant hereby undertakes:
(1) To file, during any period in which offers or sales of our securities that were not registered under the Securities Act of 1933. Each offer and sale wasare being made, in reliance on Section 4(2)a post-effective amendment to this registration statement:
(i) To include any prospectus required by section 10(a)(3) of the Securities Act of 1933, Regulation D promulgated under Section 4(2)1933;
(ii) To reflect in the prospectus any facts or events arising after the effective date of the Securities Actregistration statement (or the most recent post-effective amendment thereof) which, individually or in the aggregate, represent a fundamental change in the information set forth in the registration statement. Notwithstanding the foregoing, any increase or decrease in volume of 1933,securities offered (if the total dollar value of securities offered would not exceed that which was registered) and any deviation from the low or Rule 701 promulgated under Section 3(b)high end of the Securities Actestimated maximum offering range may be reflected in the form of 1933, as transactions by an issuer not involving any public offering or transactionsprospectus filed with the Commission pursuant to compensatory benefit plansRule 424(b) if, in the aggregate, changes in the volume and contracts relating to compensation as provided under Rule 701. The purchasers were “accredited investors,” officers, directors or employeesprice represent no more than 20 percent change in the maximum aggregate offering price set forth in the “Calculation of Registration Fee” table in the registrant or knowneffective registration statement; and
(iii) To include any material information with respect to the registrant and its management through pre-existing business relationships, friends and employees. All purchasers were provided accessplan of distribution not previously disclosed in the registration statement or any material change to all material information which they requested, and all information necessary to verify such information and was afforded access to managementin the registration statement.
(2) That, for the purpose of the registrant in connection with their purchases. All holders of the unregistered securities acquired such securities for investment and not with a view toward distribution, acknowledging such intent to the registrant. All certificates or agreements representing such securities that were issued contained restrictive legends, prohibiting further transfer of the certificates or agreements representing such securities, without such securities either being first registered or otherwise exempt from registrationdetermining any liability under the Securities Act of 1933, ineach such post-effective amendment shall be deemed to be a new registration statement relating to the securities offered therein, and the offering of such securities at that time shall be deemed to be the initial bona fide offering thereof.
(3) To remove from registration by means of a post-effective amendment any further resale or disposition.
(4) That, for the purpose of determining liability under the Securities Act of 1933 by virtue of Section 4(2).
| Option | |||||||||||||||
| Person Issued to | No. of options | Exercise Price | Term | Plan | |||||||||||
| C. Stephen Cochennet, Chief Executive Officer | 200,000 | $ | 6.25 | 4 Years | 2000 | ||||||||||
| Daran G. Dammeyer, Director | 40,000 | $ | 6.25 | 4 Years | 2002/2003 | ||||||||||
| Robert G. Wonish, Director | 40,000 | $ | 6.25 | 4 Years | 2002/2003 | ||||||||||
| Darrel G. Palmer, Director | 40,000 | $ | 6.25 | 4 Years | 2002/2003 | ||||||||||
| Mark Haas, Service provider | 60,000 | $ | 6.25 | 4 Years | 2002/2003 | ||||||||||
| Brad Kramer, Employee | 15,000 | $ | 6.25 | 4 Years | 2002/2003 | ||||||||||
| Maureen Elton, Employee | 10,000 | $ | 6.25 | 4 Years | 2002/2003 | ||||||||||
| Total: | 405,000 | ||||||||||||||
Insofar as indemnification for liabilities arising under the Securities Act of 1933 (the “Act”) may be permitted to directors, officers, and controlling persons of the small business issuerregistrant pursuant to the foregoing provisions, or otherwise, the small business issuerregistrant has been advised that in the opinion of the Securities and Exchange Commission such indemnification is against public policy as expressed in the Act and is, therefore, unenforceable. In the event that a claim for indemnification against such liabilities (other than the payment by the small business issuerregistrant of expenses incurred or paid by a director, officer or controlling person of the small business issuerregistrant in the successful defense of any action, suit or proceeding) is asserted by such director, officer or controlling person in connection with the securities being registered, the small business issuerregistrant will, unless in the opinion of its counsel the matter has been settled by controlling precedent, submit to a court of appropriate jurisdiction the question whether such indemnification by it is against public policy as expressed in the Securities Act.
SIGNATURES
Pursuant to the requirements of the Securities Act, of 1933, as amended, the registrant has duly caused this Amendment to the Registration Statementregistration statement to be signed on its behalf by the undersigned, thereunto duly authorized, in the City of Overland Park,San Antonio, State of Kansas,Texas on the 9th day of December 2009.
| By: | /s/ | |
POWER OF ATTORNEY
KNOW ALL PERSONS BY THESE PRESENTS, that each person whose signature appears below constitutes and appoints jointly and severally, Robert G. Watson, Jr., and acting singly, as the person's true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for the person and in the person's name, place and stead, in any and all capacities, to sign any and all amendments (including post-effective amendments) to this registration statement and any additional registration statements filed pursuant to Rule 462(b) under the Securities Act of 1933, and to file the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents, and each of them, full power and authority to do and perform each and every act and thing requisite and necessary to be done in connection therewith, as fully to all intents and purposes as he might or could do in person, hereby ratifying and confirming all that said attorneys-in-fact and agents, or any of them, or their or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.
Pursuant to the requirements of the Securities Act of 1933, as amended, this Amendment to the Registration Statementregistration statement has been signed by the following persons in the capacities andindicated, on the dates indicated.
Director and Chief Executive Officer | ||||
(Principal Executive Officer) | ||||
| Robert G. Watson | ||||
| /s/ | Chief Financial Officer | |||
(Principal Financial Officer and Principal Accounting Officer) | ||||
| Douglas M. Wright | ||||
| /s/ | Director | President of Corporate Marketing | ||
| R. Atticus Lowe | ||||
| /s/ | Director | |||
| Lance Helfert | ||||
| /s/ | Director | |||
| Miller | ||||
| /s/ | Director | |||
| Richard Menchaca |
INDEX
In reviewing the agreements included as exhibits to this registration statement, please remember that they are included to provide you with information regarding their terms and are not intended to provide any other factual or disclosure information about EnerJex or the other parties to the agreements. The agreements may contain representations and warranties by each of the parties to the applicable agreement. These representations and warranties have been made solely for the benefit of the parties to the applicable agreement and:
| · | should not in all instances be treated as categorical statements of fact, but rather as a way of allocating the risk to one of the parties if those statements prove to be inaccurate; |
| · | have been qualified by disclosures that were made to the other party in connection with the negotiation of the applicable agreement, which disclosures are not necessarily reflected in the agreement; |
| · | may apply standards of materiality in a way that is different from what may be viewed as material to you or other investors; and |
| · | were made only as of the date of the applicable agreement or such other date or dates as may be specified in the agreement and are subject to more recent developments. |
Accordingly, these representations and warranties may not describe the actual state of affairs as of the date they were made or at any other time. Additional information about EnerJex may be found elsewhere in this registration statement and their other public filings, which are available without charge through the SEC’s website athttp://www.sec.gov.
Exhibit No. | Description | ||
| 1.1 | Form of Underwriting Agreement++ | ||
| 2.1 | Agreement and Plan of Merger between Millennium Plastics Corporation and Midwest Energy, Inc. effective August 15, 2006 (incorporated by reference to Exhibit 2.3 to the Form 8-K filed on August 16, 2006). | ||
| 2.2 | Agreement and Plan of Merger by and among Registrant, BRE Merger Sub, Inc., Black Raven Energy, Inc. and West Coast Opportunity Fund, LLC dated July 23, 2013 (incorporated herein by reference to Exhibit 10.4 on Form 8-K filed July 29, 2013). | ||
| 3.1 | Amended and Restated Articles of Incorporation, as currently in effect (incorporated by reference to Exhibit 3.1 to the Form 10-Q filed on August 14, 2008) | ||
| 3.2 | Amended and Restated Bylaws, as currently in effect (incorporated by reference to Exhibit 3.3 to the Form SB-2 filed on February 23, 2001) | ||
| 3.3 | Certificate of Amendment of Articles of Incorporation (Previously filed) | ||
| 4.1 | Article VI of Amended and Restated Articles of Incorporation of Millennium Plastics Corporation (incorporated by reference to Exhibit 1.3 to the Form 8-K filed on December 6, 1999) | ||
| 4.2 | Article II and Article VIII, Sections 3 | ||
| 4.3 | Specimen common stock certificate (incorporated by reference to Exhibit 4.3 to | ||
| Credit Agreement with Texas Capital Bank, N.A. dated July 3, 2008 (incorporated by reference to Exhibit 10.33 to the Form 10-K filed on July 10, 2008) | |||
| Promissory Note to Texas Capital Bank, N.A. dated July 3, 2008 (incorporated by reference to Exhibit 10.34 to the Form 10-K filed on July 10, 2008) | |||
| Amended and Restated Mortgage, Security Agreement, Financing Statement and Assignment of Production and Revenues with Texas Capital Bank, N.A. dated July 3, 2008 (incorporated by reference to Exhibit 10.35 to the Form 10-K filed on July 10, 2008) | |||
| Security Agreement with Texas Capital Bank, N.A. dated July 3, 2008 (incorporated by reference to Exhibit 10.36 to the Form 10-K filed on July 10, 2008) | |||
| Amended and Restated EnerJex Resources, Inc. Stock Incentive Plan (incorporated by reference to Exhibit 10.1 to the Form 8-K filed on October 16, 2008) | |||
| Form of Officer and Director Indemnification Agreement (incorporated by reference to Exhibit 10.2 to the Form 8-K filed on October 16, 2008) | |||
| 10.7 | Euramerica Letter Agreement Amendment dated September 15, 2008 (incorporated by reference to Exhibit 10.10 to the Form | ||
| Euramerica Letter Agreement Amendment dated October 15, 2008 (incorporated by reference to Exhibit |
| Joint Operating Agreement with Pharyn Resources to explore and develop the Brownrigg Lease Press Release dated June 1, 2009 (incorporated by reference to Exhibit 99.1 to the Form 8-K filed on June 5, 2009). | |||
| Amendment 4 to Joint Exploration Agreement effective as of November 6, 2008 between MorMeg, LLC and EnerJex Resources, Inc. (incorporated by reference to Exhibit 10.15 to the Form 10-K filed July 14, 2009) | |||
| Waiver from Texas Capital Bank, N.A. dated July 14, 2009 (incorporated by reference to | |||
| First Amendment to Credit Agreement dated August 18, 2009 (incorporated by reference to the Exhibit | |||
| Standby Equity Distribution Agreement with Paladin Capital Management, S.A. dated December 3, 2009 (incorporated by reference to Exhibit 10.52 to the Form S-1 filed on December 9, 2009) | |||
| 10.14 | Amendment 5 to Joint Exploration Agreement effective as of December 31, 2009 between MorMeg LLC and EnerJex Resources, Inc. (incorporated by reference to Exhibit 10.15 to the Form 10-Q filed on February 16, 2010) | ||
| 10.15 | Second Amendment to Credit Agreement dated January 13, 2010 (incorporated by reference to Exhibit 10.16 to the Form 10-Q filed on February 16, 2010) | ||
| 10.16 | Waiver from Texas Capital Bank, N.A. dated February 10, 2009 (incorporated by reference to Exhibit 10.18 to the Form 10-Q filed on February 16, 2010) | ||
| 10.17 | Amendment 6 to Joint Exploration Agreement effective as of March 31, 2010 between MorMeg LLC and EnerJex Resources, Inc. (incorporated by reference to Exhibit 10.24 to the Form 10-K filed on July 15, 2010) | ||
| 10.18 | Separation and Settlement Agreement with C. Stephen Cochennet dated December 31, 2010 (incorporated by reference to Exhibit 10.1 to the Form 8-K filed on December 28, 2010). | ||
| 10.19 | Securities Purchase and Asset Acquisition Agreement between Enerjex Resources, Inc. and West Coast Opportunity Fund, LLC; Montecito Venture Partners, LLC; J&J Operating Company, LLC and Frey Living Trust dated December 31, 2010 (incorporated by reference to Exhibit 10.1 to the Form 8-K filed on January 6, 2011). | ||
| 10.20 | Stock Repurchase Agreement between Enerjex Resources, Inc. and Working Interest Holdings, LLC dated December 31, 2010 (incorporated by reference to Exhibit 10.2 to the Form 8-K filed on January 6, 2011). | ||
| 10.21 | Securities Purchase Agreement between Enerjex Resources, Inc. and various Investors dated December 31, 2010 (incorporated by reference to Exhibit 10.3 to the Form 8-K filed on January 6, 2011). | ||
| 10.22 | Employment Agreement between Enerjex Resources, Inc. and Robert G. Watson dated December 31, 2010 (incorporated by reference to Exhibit 10.4 to the Form 8-K filed on January 6, 2011). | ||
| 10.23 | Joint Development Agreement between Enerjex Resources, Inc. and Haas Petroleum, LLC dated December 31, 2010 (incorporated by reference to Exhibit 10.1 to the Form 8-K filed on January 27, 2011). | ||
| 10.24 | Joint Operating Agreement between Enerjex Resources, Inc. and Haas Petroleum, LLC and MorMeg, LLC dated December 31, 2010 (incorporated by reference to Exhibit 10.2 to the Form 8-K filed on January 27, 2011). | ||
| 10.25 | Third Amendment to Credit Agreement dated September 29, 2010 (incorporated by reference to Exhibit 10.33 to the Transition Report on Form 10-K filed on April 21, 2011). | ||
| 10.26 | Fourth Amendment to Credit Agreement dated December 31, 2010 (incorporated by reference to Exhibit 10.34 to the Transition Report on Form 10-K filed on April 21, 2011). | ||
| 10.27 | Letter Agreement with Registrant, James Loeffelbein, John Loeffelbein and J&J Operating dated January 14, 2011 (incorporated by reference to Exhibit 10.1 on Form 8-K filed on January 18, 2011). | ||
| 10.28 | Form of Securities Purchase Agreement among Registrant and Investors dated March 31, 2011 (incorporated by reference to Exhibit 10.1 on Form 8-K filed on April 4, 2011). | ||
| 10.29 | Form of Warrant among Registrant and Investors dated March 31, 2011 (incorporated by reference to Exhibit 10.2 on Form 8-K filed on April 4, 2011). | ||
| 10.30 | Form of Stock Redemption Agreement among Registrant and Working Interest Holdings, LLCs dated March 31, 2011 (incorporated by reference to Exhibit 10.1 on Form 8-K filed on April 4, 2011). | ||
| 10.31 | Amended and Restated Credit Agreement dated October 3, 2011 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on October 6, 2011). | ||
| 10.32 | Option and Joint Development Agreement by and among Registrant and MorMeg, LLC dated August 2011 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on November 15, 2011). |
| 10.33 | Rantoul Partners General Partnership Agreement dated December 14, 2011 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on December 14, 2011). | ||
| 10.34 | First Amendment to Amended and Restated Credit Agreement dated December 14, 2011 (incorporated herein by reference to Exhibit 10.2 on Form 8-K filed on December 14, 2011). | ||
| 10.35 | First Amendment to General Partnership Agreement for Rantoul Partners dated March 30, 2012 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on April 5, 2012). | ||
| 10.36 | Share Option Agreement by and among the EnerJex and Enutroff dated August 31, 2012 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on October 10, 2012). | ||
| 10.37 | Second Amendment to Amended and Restated Credit Agreement dated August 31, 2012 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on November 8, 2012). | ||
| 10.38 | Third Amendment to Amended and Restated Credit Agreement dated November 2, 2012 (incorporated herein by reference to Exhibit 10.2 on Form 8-K filed on November 8, 2012). | ||
| 10.39 | Securities and Asset Purchase Agreement by and among Registrant and James Loeffelbein and Enutroff dated November 3, 2012 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on January 7, 2013). | ||
| 10.40 | Second Amendment to General Partnership Agreement of Rantoul Partners dated November 27, 2012 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on November 29, 2012). | ||
| 10.41 | Amended and Restated Employment Agreement by and among Registrant and Robert G. Watson, Jr. dated December 31, 2012 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on January 4, 2013). | ||
| 10.42 | Partial Assignment of Assets by and among Rantoul Partners and Working Interest, LLC, dated December 31, 2012 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed on January 30, 2013). | ||
| 10.43 | Fourth Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank dated December 31, 2012 (incorporated herein by reference to Exhibit 10.2 on Form 8-K filed on January 30, 2013). | ||
| 10.44 | First Amendment to Amended & Restated Mortgage Security Agreement, Financing Statement and Assignment of Production by and among Working Interest, LLC and Texas Capital Bank dated December 31, 2012 (incorporated herein by reference to Exhibit 10.3 on Form 8-K filed on January 30, 2013). | ||
| 10.45 | Mortgage, Security Agreement, Financing Statement and Assignment of Production and Revenues by and among Working Interest, LLC and Texas Capital Bank dated December 31, 2012 (incorporated herein by reference to Exhibit 10.4 on Form 8-K filed on January 30, 2013). | ||
| 10.46 | Fifth Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank, N.A. dated September 30, 2013 (incorporated herein by reference to Exhibit 10.1 on Form 8-K filed October 1, 2013). | ||
| 21.1 | |||
| 23.1 | Consent of | ||
| 23.2 | Consent of | ||
| 23.3 | Consent of | ||
| 24.1 | Power of Attorney (included with signatures). |
(b)Financial Statement Schedules
* Filed herewith.
++ To be filed by amendment.
| 64 |