UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C.  20549

 

FORM 10-Q

 

þ       QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

For the quarterly period ended June 30, 2013

 

¨       TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

 

Commission file number 000-30234

 

 

ENERJEX RESOURCES, INC.

(Exact name of registrant as specified in its charter)

 

Nevada		88-0422242
(State or other jurisdiction of incorporation or		(I.R.S. Employer Identification No.)
organization)
4040 Broadway
Suite 508
San Antonio, Texas		78209
(Address of principal executive offices)		(Zip Code)

 

(210) 451-5545

(Registrant's telephone number, including area code)

 

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.     Yes    þ        No    ¨

 

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

 

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.

 

Large accelerated filer  ¨		Accelerated filer  ¨
Non-accelerated filer  ¨  (Do not check if a smaller reporting company)		Smaller reporting company  þ

 

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes    ¨      No     þ

 

The number of shares of Common Stock, $0.001 par value, outstanding on August 12, 2013 was 67,926,529 shares.

 

 

ENERJEX RESOURCES, INC.

FORM 10-Q

TABLE OF CONTENTS

 

		Page
PART I     FINANCIAL STATEMENTS
ITEM 1.	FINANCIAL STATEMENTS	2
	Condensed Consolidated Balance Sheets	2
	Condensed Consolidated Statements of Operations	3
	Condensed Consolidated Statements of Cash Flows	4
	Notes to Condensed Consolidated Financial Statements	5
	FORWARD-LOOKING STATEMENTS	10
ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	11
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	17
ITEM 4.	CONTROLS AND PROCEDURES	17
PART II    OTHER INFORMATION
ITEM 1.	LEGAL PROCEEDINGS	17
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	17
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	17
ITEM 4.	(REMOVED AND RESERVED)	17
ITEM 5.	OTHER INFORMATION	17
ITEM 6.	EXHIBITS	18
SIGNATURES		20

  

 

PART 1 – FINANCIAL INFORMATION

 

ITEM 1. FINANCIAL STATEMENTS

EnerJex Resources, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

Unaudited

 

		June 30,				December 31,
		2013				2012
Assets
Current assets:
Cash		$	231,329			$	767,494
Accounts receivable			988,264				1,221,962
Marketable securities			1,018,573				1,018,573
Deposits and prepaid expenses			611,435				528,468
Total current assets			2,849,601				3,536,497
Fixed assets, net of accumulated depreciation			284,442				309,877
Other assets:
Oil properties using full-cost accounting, net of accumulated DD&A			34,963,246				33,202,898
Total assets		$	38,097,289			$	37,049,272
Liabilities and Stockholders' Equity
Current liabilities:
Accounts payable		$	1,484,021			$	2,384,090
Accrued liabilities			598,341				590,205
Derivative liability			789,055				757,181
Note payable			425,000				825,000
Total current liabilities			3,296,417				4,556,476
Asset retirement obligation			1,336,533				1,336,151
Long-term debt			11,000,000				8,500,000
Derivative liability			420,739				1,043,114
Total non-current liabilities			12,757,272				10,879,265
Total liabilities			16,053,689				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 73,676,529  at June 30, 2013 and 73,586,529 at December 31, 2012			73,677				73,587
Treasury Stock, 5,750,000 shares			(2,551,000	)			(2,551,000	)
Paid-in capital			45,437,796				45,352,096
Accumulated other comprehensive income			(552,589	)			(552,589	)
Retained (deficit)			(20,369,064	)			(20,713,343	)
Total stockholder’s equity			22,043,600				21,613,531
Total liabilities and stockholders' equity		$	38,097,289			$	37,049,272

 

See Notes to Condensed Consolidated Financial Statements.

 

 

EnerJex Resources, Inc. and Subsidiaries

Condensed Consolidated Statements of Operations

(Unaudited)

 

		For the Three Months Ended								For the Six Months Ended
		June 30,								June 30,
		2013				2012				2013				2012
Oil revenues		$	2,196,736			$	2,049,165			$	4,534,037			$	3,952,057
Expenses:
Direct operating costs			751,957				745,504				1,534,029				1,354,583
Depreciation, depletion and  amortization			418,561				407,916				863,098				830,519
Professional fees			269,257				339,757				625,479				672,729
Salaries			185,978				109,498				431,989				243,380
Administrative expense			174,243				202,029				313,647				445,926
Total expenses			1,799,996				1,804,704				3,768,242				3,547,137
Income from operations			396,740				244,461				765,795				404,920
Other income (expense):
Interest expense			(137,128	)			(69,947	)			(255,373	)			(137,607	)
Gain on derivatives			407,759				2,877,419				167,818				1,690,480
Other income			49,214				9,793				58,381				22,251
Total other income (expense)			319,845				2,817,265				(29,174	)			1,575,124
Net income		$	716,585			$	3,061,726			$	736,621			$	1,980,044
Net income attributed to EnerJex Resources, Inc.			716,585				2,970,576				736,621				1,834,683
Net income attributed to non-controlling interest in subsidiary							91,150								145,361
Net income		$	716,585			$	3,061,726			$	736,621			$	1,980,044
Net income per share basic and diluted		$	.01			$	.04			$	0.01			$	0.03
Weighted average shares			67,837,518				69,707,847				67,837,026				69,694,505

 

See Notes to Condensed Consolidated Financial Statements.

 

 

EnerJex Resources, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(Unaudited)

 

		For the Six Months Ended
		June 30,
		2013				2012
Cash flows from operating activities
Net income		$	736,621			$	1,980,044
Depreciation, depletion and amortization			863,098				830,519
Stock, options and warrants issued for services			140,496				88,462
Accretion of asset retirement obligation			56,386				47,568
Settlement of asset retirement obligation			(36,758	)			-
Loss  on derivatives			(590,501	)			(2,302,176	)
Loss on sale of fixed assets			7,785				2,662
Adjustments to reconcile net income to cash from operating activities:
Accounts receivable			233,698				208,247
Prepaid expenses			(137,674	)			(75,088	)
Accounts payable			(900,069	)			(233,523	)
Accrued liabilities			(16,556	)			20,953
Cash flows from operating activities			356,526				567,668
Cash flows from investing activities
Purchase of fixed assets			(41,418	)			(4,237	)
Additions to oil  properties			(3,035,741	)			(4,551,045	)
Proceeds from the sale of assets			452,118				300
Cash flows from investing activities			(2,625,041	)			(4,554,982	)
Cash flows from financing activities
Payments on long-term debt			-				(17,484	)
Payments on notes payable			(400,000	)			-
Proceeds from borrowings			2,500,000				1,100,000
Distribution to non controlling  interest in subsidiary			-				(236,376	)
Sale of non controlling  interest in subsidiary			-				2,000,000
Dividends paid on preferred stock			(367,650	)			(59,996	)
Cash flows from financing activities			1,732,350				2,786,144
Net decrease in cash			(536,165	)			(1,201,170	)
Cash – beginning			767,494				2,770,440
Cash – ending		$	231,329			$	1,569,270
Supplemental disclosures:
Interest paid		$	117,588			$	90,039
Income taxes paid		$	-			$	-
Non-cash transactions:
Share based  payments issued for services		$	140,496			$	88,462

 

See Notes to Condensed Consolidated Financial Statements.

 

 

EnerJex Resources, Inc. and Subsidiaries

Notes to Condensed Consolidated Financial Statements

 

Note 1 – Basis of Presentation

 

The unaudited condensed consolidated financial statements have been prepared in accordance with United States generally accepted accounting principles for interim financial information and with the instructions to Form 10-Q and reflect all adjustments which, in the opinion of management, are necessary for a fair presentation.  All such adjustments are of a normal recurring nature.  The results of operations for the interim period are not necessarily indicative of the results to be expected for a full year.  Certain amounts in the prior year statements have been reclassified to conform to the current year presentations.  The statements should be read in conjunction with the financial statements and footnotes thereto included in our Annual Report Form 10-K for the fiscal year ended December 31, 2012.

 

Our consolidated financial statements include the accounts of our wholly-owned subsidiaries, EnerJex Kansas, Inc., DD Energy, Inc., Black Sable Energy, LLC, and Working Interest, LLC for the three month and six month periods ended June 30, 2013 and for the year ended December 31, 2012. The accounts of Rantoul Partners, a general partnership in which we held a majority and controlling interest are included in the Statements of Operations and Statement of Cash Flows for the three month and six month periods ended June 30, 2012. On December 31, 2012 we distributed all of the assets of the partnership to the partners and dissolved Rantoul Partners. Accordingly, the Rantoul Partners accounts are still reflected in certain 2012 financial statements. All intercompany transactions and accounts have been eliminated in consolidation.

 

Note 2 - Stock Options

 

A summary of stock options is as follows:

 

		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				-				-
Exercised			-				-				-				-
Outstanding June 30, 2013			1,717,000			$	0.54				550,000			$	0.70

 

The fair value of options granted was determined by using the Black Scholes model. The Company expensed $21,551 as compensation expense in three month period ended June 30, 2013.

 

Note 3 – 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 identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). ASC Topic 820-10 defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants on the measurement date. A fair value measurement assumes that the transaction to sell the asset or transfer the liability occurs in the principal market for the asset or liability. The three levels of the fair value hierarchy under ASC Topic 820-10 are described below:

 

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 our debt approximates fair value at June 30, 2013.

 

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 our marketable securities to be Level 3

 

 

Our derivative instruments consist of variable to fixed price commodity swaps.

 

		Fair Value Measurement
		Level 1				Level 2				Level 3
Crude oil contracts		$	-			$	(1,209,794	)		$	-
Marketable Securities		$	-			$	-			$	1,018,573

 

Note 4 - Asset Retirement Obligation

 

Our asset retirement obligations relate to the liabilities associated with the abandonment of oil 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 obligations, December 31, 2012		$	1,336,151
Liabilities incurred during the period			26,007
Liabilities associated with assets sold during the period			(82,011	)
Accretion			56,386
Asset retirement obligations, June 30, 2013		$	1,336,533

 

Note 5 - Derivative Instruments

 

We have entered into certain derivative or physical arrangements with respect to portions of our 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 risk, allow us to achieve a more predictable cash flow and to reduce exposure to commodity price fluctuations. However, derivative arrangements limit the benefit of increases in the prices of crude oil. Moreover, our derivative arrangements apply only to a portion of our production.

 

We have an Intercreditor Agreement in place between us, 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 security interests resulting from our derivative arrangements. Therefore, we are not required to post additional collateral, including cash.

 

The following derivative contracts were in place at June 30, 2013:

 

		Term				Monthly Volumes		Price/Bbl				Fair Value
Crude oil swap			1/12-12/14			1,800 Bbls		$	76.74			$	(771,420	)
Crude oil swap			7/11-12/15			2,560 Bbls			83.70				(432,365	)
Crude oil collar			5/13-12/13			1,587 Bbls			90.00 – 94.50				(10,752	)
Crude oil swap			1/14-12/14			1,369 Bbls			90.25				(5,852	)
Crude oil swap			7/13–12/13			1,300 Bbls			97.10				10,595
												$	(1,209,794	)

 

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. 

 

Note 6 – Note Payable

 

On November 30, 2012 we purchased two million shares of common stock and certain assets from a shareholder of the Company for consideration of $323,035 in cash (including an option payment that we previously made to the selling shareholder) and a promissory note of $825,000 bearing an interest rate of twenty-four hundredths percent (0.24%).

 

On March 28, 2013, we made a $200,488 payment on the promissory note consisting of $200,000 of principal and $488 of accrued interest. On June 27, 2013, we made a payment of $200,374 on the promissory note consisting of $200,000 of principal and $374 of accrued interest. The remaining outstanding principal on the promissory note amortizes as follows: i) $200,000 plus accrued interest on or before September 30, 2013, and ii) $225,000 plus accrued interest on or before December 31, 2013.

 

 

Note 7 - Long-Term Debt

 

Senior Secured Credit Facility

 

On October 3, 2011, the Company and DD Energy, Inc., EnerJex Kansas, Inc., Black Sable Energy, LLC and Working Interest, LLC, refered to collectively in this context as the “Borrowers”, entered into an Amended and Restated Credit Agreement with Texas Capital Bank, and 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 Agreement 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 a 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, for 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 per 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 a pricing grid ranging from 0.00% to 0.75% for the Base Rate Margin and 2.25% to 3.00% for the Floating Rate Margin based on the Company's Borrowing Base Utilization Percentage (as defined in the Amended and Restated Credit Agreement).

 

The Borrowers entered into a First Amendment to 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.

  

On August 31, 2012, the Borrowers entered into a Second Amendment to the Amended and Restated Credit Agreement with Texas Capital Bank. The Second Amendment reflects the following changes: (i) the reduction of the minimum interest rate to 3.75%, ii) an increase in the borrowing base to $7.0 million, iii) the addition of a provision resulting in an event of default if Robert G. Watson Jr. ceases to be the chief executive officer of EnerJex for any reason and a successor reasonably acceptable to Administrative Agent is not appointed within one hundred twenty days (120) thereafter, and iv) the addition of new leases to the collateral pool.

 

On November 2, 2012, the Borrowers entered into a Third Amendment to the Amended and Restated Credit Agreement with Texas Capital Bank. The Third Amendment reflects the following changes: i) an increase in the borrowing base to $12.150 million, ii) the addition of a provision permitting the repurchase of up to $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, the 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 consented to the restructuring transactions related to the dissolution of Rantoul Partners, and ii) Texas Capital Bank terminated a Limited Guaranty, as defined in the Credit Agreement, executed by Rantoul Partners in favor of Texas Capital Bank.

 

On April 16, 2013, Texas Capital Bank increased our 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 third quarter of 2013 and we expect increases in our oil production and the maturity of our existing oil producing wells to result in an additional borrowing base increases.

 

This senior secured credit facility matures on October 3, 2015, unless extended by mutual agreement. On the maturity date all obligations plus accrued interest must be repaid.

 

 

Note 8 Commitments & Contingencies

 

As of June 30, 2013 the Company had an outstanding irrevocable letter of credit in the amount of $50,000 issued in favor of the Texas Railroad Commission. The letter of credit is required by the Texas Railroad Commission for all companies operating in the state of Texas with production greater than limits they prescribe.

 

Note 9 Equity Transactions

 

On January 1, 2013, 300,000 warrants with a strike price equal to $.70 were issued to a consulting firm as compensation for service. Half of these warrants vested on March 31, 2013 and the other half of these warrants vested on June 30, 2013. The fair market value of the warrants was calculated by the Black Scholes model. We expensed $16,180 as professional fees in the quarter ended March 31, 2013 and $24,609 in the quarter ended June 30, 2013.

 

Note 10 Subsequent Events

 

We have reviewed all material events through the date of this report in accordance with ASC 855-10.

 

On July 15, 2013, EnerJex Resources, Inc.'s Audit Committee approved the engagement of L.L. Bradford & Company, LLC as its independent registered public accounting firm for the Company's fiscal year ending December 31, 2013. Concurrent with its appointment of L.L. Bradford & Company, LLC, the Audit Committee dismissed Weaver Martin & Samyn, LLC, which served as the Company's independent registered public accountant for the fiscal years ended December 31, 2012, and December 31, 2011.

  

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.

 

As more fully described in footnotes 2 and 9, 550,000 warrants were issued to a consulting firm as compensation for service. Subsequent to June 30, 2013 these warrants expired, unexercised.

 

 

FORWARD-LOOKING STATEMENTS

 

This report contains forward-looking statements. These forward-looking statements are subject to a number of risks and uncertainties, many of which are beyond our control. All statements, other than statements of historical fact, contained in this report, including statements regarding future events, our future financial performance, business strategy and plans and objectives 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 "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, including the risks outlined under "Risk Factors" or elsewhere in this report, which may cause 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 competitive 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 business or the extent to which any factor, or combination 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:

 

	·	inability to attract and obtain additional development capital;
	·	inability to achieve sufficient future sales levels or other operating results;
	·	inability to efficiently manage our operations;
	·	effect of our hedging strategies on our results of operations;
	·	potential default under our secured obligations or material debt agreements;
	·	estimated quantities and quality of oil reserves;
	·	declining local, national and worldwide economic conditions;
	·	fluctuations in the price of oil;
	·	continued weather conditions that impact our abilities to efficiently manage our drilling and development activities;
	·	the inability of management to effectively implement our strategies and business plans;
	·	approval of certain parts of our operations by state regulators;
	·	inability to hire or retain sufficient qualified operating field personnel;
	·	increases in interest rates or our cost of borrowing;
	·	deterioration in general or regional (especially Eastern Kansas and South Texas) economic conditions;
	·	adverse state or federal legislation or regulation that increases the costs of compliance, or adverse findings by a regulator with respect to existing operations;
	·	the occurrence of natural disasters, unforeseen weather conditions, or other events or circumstances that could impact our operations or could impact the operations of companies or contractors we depend upon in our operations;
	·	inability to acquire mineral leases at a favorable economic value that will allow us to expand our development efforts;
	·	adverse state or federal legislation or regulation that increases the costs of compliance, or adverse findings by a regulator with respect to existing operations; and
	·	changes in U.S. GAAP or in the legal, regulatory and legislative environments in the markets in which we operate.

 

You should not place undue reliance on any forward-looking statement, each of which applies only as of the date of this report. Except as required by law, we undertake no obligation to update or revise publicly any of the forward-looking statements after the date of this report to conform our statements to actual results or changed expectations. For a detailed description of these and other factors that could cause actual results to differ materially from those expressed in any forward-looking statement, please see "Risk Factors" in this document and in our Annual Report on Form 10-K for the fiscal year ended December 31, 2012.

 

All references in this report to "we," "us," "our," "company" and "EnerJex" refer to EnerJex Resources, Inc. and our wholly-owned operating subsidiaries, EnerJex Kansas, Inc., DD Energy, Inc., Black Sable Energy, LLC, and Working Interest, LLC, unless the context requires otherwise. The accounts of Rantoul Partners, a general partnership in which we held a majority and controlling interest are included in the Statements of Operations and Statement of Cash Flows for the three month and six month periods ended June 30, 2012. On December 31, 2012 we distributed all of the assets of the partnership to the partners and dissolved Rantoul Partners. Accordingly, the Rantoul Partners accounts are still reflected in certain 2012 financial statements. We report our financial information on the basis of a December 31 ^st fiscal year end.

 

AVAILABLE INFORMATION

 

We file annual, quarterly and other reports and other information with the SEC.  You can read these SEC filings and reports over the Internet at the SEC's website at www.sec.gov or on our website at www.enerjex.com .  You can also obtain copies of the documents at prescribed rates by writing to the Public Reference Section of the SEC at 100 F Street, NE, Washington, DC 20549 on official business days between the hours of 10:00 am and 3:00 pm.  Please call the SEC at (800) SEC-0330 for further information on the operations of the public reference facilities. We will provide a copy of our annual report to security holders, including audited financial statements, at no charge upon receipt to of a written request to us at EnerJex Resources, Inc., 4040 Broadway, Suite 508, San Antonio, Texas 78209. 

 

 

INDUSTRY AND MARKET DATA

 

The market data and certain other statistical information used throughout this report are based on independent industry publications, government publications, reports by market research firms or other published independent sources. In addition, some data are based on our good faith estimates.

 

ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS.

 

The following discussion of our financial condition and results of operations should be read in conjunction with our financial statements and the related notes to our financial statements included elsewhere in this report. In addition to historical financial information, the following discussion and analysis contains forward-looking statements that involve risks, uncertainties and assumptions. Our actual results and timing of selected events may differ materially from those anticipated in these forward-looking statements as a result of many factors, including those discussed under ITEM 1A. Risk Factors and elsewhere in this report.

 

Overview

Our principal strategy is to acquire, develop, explore and produce domestic onshore oil properties. Our business activities are currently focused in Eastern Kansas and South Texas.

 

The 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. Approximately 44 million barrels of oil were produced in Kansas during 2012. Twenty companies accounted for approximately 35% of the state’s total production, with the remaining 65% produced by more than 3,500 active producers.

 

In addition to significant historical oil 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 development activities:

 

·

Numerous Acquisition Opportunities in Fragmented Markets. The exploration and production business in Eastern Kansas is highly fragmented and consists of many small operators that operate producing oil properties on relatively small budgets. Consequently, numerous acquisition opportunities with drilling and expansion potential exist in the area.

 

·

Opportunity to Enhance Operational Efficiency of Mature Leases.   Many potential acquisition targets include significant opportunities for enhanced operational efficiencies and increased ultimate recoveries of oil through the application of modern engineering technologies, professional approaches to reservoir engineering and operations management, and the potential application of a number of enhanced oil recovery technologies.

 

·

Opportunity to Reduce Operating Costs per Barrel Through Economies of Scale.   A significant portion of expenses at the field level are fixed (primarily labor and equipment). These costs are scalable, and lease operating expenses per barrel may be significantly reduced by increasing production in current areas of operation by drilling low risk development wells, acquiring producing properties in close proximity to existing operations, and utilizing modern enhanced oil recovery technologies.

 

·

Large Oil Reserves in Place and Relatively Low Exploration Risk.   A majority of the oil reserves in Eastern Kansas are present at relatively shallow horizons (most at a depth of less than 3,000 feet) and contain significant volumes of oil in place. These shallow reservoirs often have relatively low reservoir pressure and lack a strong natural drive mechanism. As a result, the ultimate recovery of oil in place can be significantly increased through the application of secondary recovery technologies.

 

The Opportunity in South Texas

 

Technological advances in the oil industry have made great strides over the last decade, especially in the area of 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 commodity price environment provide an opportunity for operators to economically produce oil from reservoirs that were discovered in the past, yet were never fully developed due to technology and economic constraints.

 

Recent Developments

 

The following is a brief description of our most significant corporate developments that have occurred since the end of 2012:

 

·

From January 1, 2013 to June 30, 2013 we drilled 11 new oil wells and 10 new secondary recovery water injection wells in our Mississippian Project located in Southeast Kansas.

 

·

During the first quarter and second quarters of 2013, we drilled 13 new oil wells and 8 new secondary recovery wells in our Cherokee Project located in Eastern Kansas.

 

  

Net Production, Average Sales Price and Average Production and Lifting Costs

 

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			$	92.02
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 properties is not included in production costs.

(2) Direct lifting costs do not include impairment expense or depreciation, depletion and amortization.

 

Results of Operations for the Six Months Ended June 30, 2013 and 2012 compared.

 

Income :

 

		Three Months Ended								Increase /				Six Months Ended								Increase /
		June 30,								(Decrease)				June 30,								(Decrease)
		2013				2012				$				2013				2012				$
Oil revenues		$	2,196,736			$	2,049,165			$	147,571			$	4,534,037			$	3,952,057			$	581,980

 

Revenues

 

Oil revenues for the six months ended June 30, 2013 were $4,534,037 compared to revenues of $3,952,057 in the six months ended June 30, 2012. Revenues increased as a result of higher oil production offset by slightly lower oil prices.

 

  

Expenses:

		Three Months Ended								Increase /				Six Months Ended								Increase /
		June 30,								(Decrease)				June 30,								(Decrease)
		2013				2012				$				2013				2012				$
Production expenses:
Direct operating costs		$	751,957			$	745,504			$	6,453			$	1,534,029			$	1,354,583			$	179,446
Depreciation, depletion and amortization			418,561				407,916				10,645				863,098				830,519				32,579
Total production expenses			1,170,518				1,153,420				17,098				2,397,127				2,185,102				212,025
General expenses:
Professional fees			269,257				339,757				(70,500	)			625,479				672,729				(47,250	)
Salaries			185,978				109,498				76,480				431,989				243,380				188,609
Administrative expense			174,243				202,029				(27,786	)			313,647				445,926				(132,279	)
Total general expenses			629,478				651,284				(21,806	)			1,371,115				1,362,035				9,080
Total production and general expenses			1,799,996				1,804,704				(4,708	)			3,768,242				3,547,137				221,105
Income from operations			396,740				244,461				152,279				765,795				404,920				360,875
Other income (expense)
Interest expense			(137,128	)			(69,947	)			(67,181	)			(255,373	)			(137,607	)			(117,766	)
Gain on derivatives			407,759				2,877,419				(2,469,660	)			167,818				1,690,480				(1,522,662	)
Other income			49,214				9,793				39,421				58,381				22,251				36,130
Total other income (expense)			319,845				2,817,265				(2,497,420	)			(29,174	)			1,575,124				(1,604,298	)
Net income		$	716,585			$	3,061,726			$	(2,345,141	)		$	736,621			$	1,980,044			$	(1,243,423	)

 

Direct Operating Costs

 

Direct operating costs primarily include direct labor and equipment costs related to pumping, gauging, pulling, well repairs, and general maintenance requirements. These costs also include certain contract labor costs, and other non-capitalized expenses. Direct operating costs for the six months ended June 30, 2013 were $1,534,029 compared to $1,354,583 for the six months ended June 30, 2012. Direct operating costs increased $179,446 primarily due to an increase in production.

 

Depreciation, Depletion and Amortization

 

Depreciation, depletion and amortization for the six months ended June 30, 2013 was $863,098 compared to $830,519 for the six months ended June 30, 2012.

 

Professional Fees

 

Professional fees for the six months ended June 30, 2013 were $625,479 compared to $ 672,729 for the six months ended June 30, 2012. Professional fees decreased as a result of lower legal and investment banking fees incurred during the first half of 2013 compared to the first half of 2012.

 

 

 

Salaries

 

Salaries for the six months ended June 30, 2013 were $431,989 compared to $243,380 for the six months ended June 30, 2012.  Salaries increased due to the addition of five employees during the last half of 2012 and first half of 2013.

 

Administrative Expenses

 

Administrative expenses for the six months ended June 30, 2013 were $313,647 compared to $445,926 for the six months ended June 30, 2012. The decrease in administrative expenses was due primarily to decreased insurance, rent and general office and office supply expenditures in 2013 compared to the same period in 2012.

 

Interest Expense

 

Interest expense for the six months ended June 30, 2013 was $255,373 compared to $137,607 for the six months ended June 30, 2012. Interest expense increased due to increased borrowings under our Credit Facility.

 

Gain (Loss) on Derivatives

 

A gain of $167,818 resulted from the “mark to market” valuation of our derivative contracts at June 30, 2013. The gain was due to lower prices for oil futures at June 30, 2013 than at December 31, 2012.

 

Net Income (Loss)

 

Net income for the six months ended June 30, 2013 was $736,621 compared to net income of $1,980,044 for the six months ended June 30, 2012.  The decrease in net income was due primarily to a reduction of unrealized gain on derivatives resulting from the “mark to market” valuation of our derivative contracts at June 30, 2013 as compared to June 30, 2012.

 

Liquidity and Capital Resources

 

Liquidity is a measure of a company'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. We 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 current assets, total current liabilities and working capital.

 

		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 October 3, 2011, the Company and DD Energy, Inc., EnerJex Kansas, Inc., Black Sable Energy, LLC and Working Interest, LLC Borrowers entered into an Amended and Restated Credit Agreement with Texas Capital Bank, and 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 Agreement 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, for 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 per 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 a pricing grid ranging from 0.00% to 0.75% for the Base Rate Margin and 2.25% to 3.00% for the Floating Rate Margin based on the Company's Borrowing Base Utilization Percentage (as defined in the Amended and Restated Credit Agreement).

 

Borrowers entered into a First Amendment to 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.

 

 

On August 31, 2012, Borrowers entered into a Second Amendment to the Amended and Restated Credit Agreement with Texas Capital Bank. The Second Amendment reflects the following changes: (i) the reduction of the minimum interest rate to 3.75%, ii) an increase in the borrowing base to $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 days (120) thereafter, and iv) the addition of new leases to the collateral pool.

 

On November 2, 2012, Borrowers entered into a Third Amendment to the Amended and Restated Credit Agreement with Texas Capital Bank. The Third Amendment reflects the following changes: i) an increase in the borrowing base to $12.150 million, ii) the addition of a provision permitting the repurchase of up to $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 consented to the restructuring transactions related to the dissolution of Rantoul Partners, and ii) Texas Capital Bank terminated a Limited Guaranty, as defined in the Credit Agreement, executed by Rantoul Partners in favor of Texas Capital Bank.

 

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 third quarter of 2013 and we expect increases in our oil production and the maturity of our existing oil producing wells to result in an additional borrowing base increase.

 

Satisfaction of our cash obligations for the next 12 months

 

We intend to meet our near term cash obligations through financings under our credit facility with Texas Capital Bank and through cash 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.

 

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 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 employees and we currently have 18 full-time employees, including field personnel. As production and drilling 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 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. 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.

 

 

Critical Accounting Policies and Estimates

 

Our critical accounting estimates include the value our oil and gas properties, asset retirement obligations, and share-based payments.

 

Oil Properties

 

The accounting for our business is subject to special accounting rules that are unique to the oil industry. There are two allowable methods of accounting for oil 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 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 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 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, 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 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 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 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 remains volatile.

 

ITEM 3.  QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.

 

We are a smaller reporting Company as defined by Rule 12b-2 under the Securities Exchange Act of 1934, and are not required to provide the information required under this item.

 

ITEM 4. CONTROLS AND PROCEDURES .

 

Our chief executive officer and principal financial officer, Robert G. Watson, Jr., evaluated the effectiveness of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934, as amended) as of the end of the period covered by this Report. Based on the evaluation, Mr. Watson concluded that our disclosure controls and procedures are effective in timely altering him to material information relating to us (including our consolidated subsidiaries) required to be included in our periodic SEC filings.

 

There were no changes in our internal control over financial reporting that occurred during our most recent fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

 

PART II—OTHER INFORMATION

 

ITEM 1.  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 transition report, 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. There can be no assurance of the outcome in the litigation, including whether and in what amount we may recover damages. On June 30, 2012, the defendants answered the complaint and filed a counterclaim against us for $492,133.95. This amount is already reflected as a liability under accounts payable on our balance sheet.

 

ITEM 2.  UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS.

 

None

 

ITEM 3. DEFAULTS UPON SENIOR SECURITIES.

 

None.

 

ITEM 4. (REMOVED AND RESERVED).

 

ITEM 5. OTHER INFORMATION.

 

None.

 

 

ITEM 6.  EXHIBITS.

 

Exhibit No.		Description
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)
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
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 & 6 of Amended and Restated Bylaws of Millennium Plastics Corporation (incorporated by reference to Exhibit 4.1 to the Form SB-2 filed on February 23, 2001)
4.3		Specimen common stock certificate (incorporated by reference to Exhibit 4.3 to the Form S-1/A filed on May 27, 2008)
4.4		Certificate of Designation (incorporated by reference to Exhibit 4.1 to the Form 8-K filed on January 6, 2011).
10.1		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)
10.2		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)
10.3		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)
10.4		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)
10.5		Letter Agreement with Debenture Holders dated July 3, 2008 (incorporated by reference to Exhibit 10.37 to the Form 10-K filed on July 10, 2008)
10.6†		C. Stephen Cochennet Employment Agreement dated August 1, 2008 (incorporated by reference to Exhibit 10.1 to the Form 8-K filed on August 1, 2008)
10.7†		Dierdre P. Jones Employment Agreement dated August 1, 2008 (incorporated by reference to Exhibit 10.2 to the Form 8-K filed on August 1, 2008)
10.8†		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)
10.9		Form of Officer and Director Indemnification Agreement (incorporated by reference to Exhibit 10.2 to the Form 8-K filed on October 16, 2008)
10.10		Euramerica Letter Agreement Amendment dated September 15, 2008 (incorporated by reference to Exhibit 10.10 to the Form 8-K filed on September 18, 2008)
10.11		Euramerica Letter Agreement Amendment dated October 15, 2008 (incorporated by reference to Exhibit 10.11 to the Form 8-K filed on October 21, 2008)
10.12(a) †		C. Stephen Cochennet Rescission of Option Grant Agreement dated  November 17, 2008 (incorporated by reference to Exhibit 10.38(a) to the Form 10-Q filed on February 23, 2009)
10.12(b) †		Dierdre P. Jones Rescission of Option Grant Agreement dated November 17, 2008 (incorporated by reference to Exhibit 10.38(b) to the Form 10-Q filed on February 23, 2009)
10.12		Daran G. Dammeyer Rescission of Option Grant Agreement dated November 17, 2008 (incorporated by reference to Exhibit 10.38(c) to the Form 10-Q filed on February 23, 2009)
10.12(d)		Darrel G. Palmer Rescission of Option Grant Agreement dated November  17, 2008 (incorporated by reference to Exhibit 10.38(d) to the Form 10-Q filed on February 23, 2009)
10.12(e)		Dr. James W. Rector Rescission of Option Grant Agreement dated November 17, 2008 (incorporated by reference to Exhibit 10.38(e) to the Form 10-Q filed on February 23, 2009)
10.12(f)		Robert G. Wonish Rescission of Option Grant Agreement dated November 17, 2008 (incorporated by reference to Exhibit 10.38(f) to the Form 10-Q filed on February 23, 2009)
10.13		Letter Agreement with Debenture Holders dated June 11, 2009 (incorporated by reference to  Exhibit 10.1 to the Form 8-K filed on June 16, 2009)
10.14		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)
10.15		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)

 

 

 

10.16		Waiver from Texas Capital Bank, N.A. dated  July 14, 2009 (incorporated by reference to Exhibit 10.16 to Form 10-K filed July 14, 2009)
10.17		First Amendment to Credit Agreement dated August 18, 2009 (incorporated by reference to the Exhibit 10.12 to the Form 10-Q filed August 18, 2009)
10.18		Debenture Holder Amendment Letter dated November 16, 2009 (incorporated by reference to the Exhibit 10.13 to the Form 10-Q filed November 20, 2009)
10.19		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)
10.20		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)
10.21		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)
10.22		Debenture Holder Amendment Letter dated January 27, 2010 (incorporated by reference to Exhibit 10.17 to the Form 10-Q filed on February 16, 2010)
10.23		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)
10.24		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)
10.25		Debenture Holder Amendment Letter dated April 1, 2010 (incorporated by reference to Exhibit 10.25 to the Form 10-K filed on July 15, 2010)
10.26		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).
10.27		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).
10.28		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).
10.29		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).
10.30		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).
10.31		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).
10.32		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).
10.33		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).
10.34		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).
10.35		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).
10.36		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).
10.37		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).
10.38		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).
10.39		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).
10.40		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).
10.41		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).
10.42		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).
10.43		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).
31.1		Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
31.2		Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
32.1		Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
32.2		Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

 

† Indicates management contract or compensatory plan or arrangement.

 

 

 SIGNATURES

 

In accordance with the requirements of the Exchange Act, the registrant caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

 

ENERJEX RESOURCES, INC.
(Registrant)
By:	/s/ Robert G. Watson, Jr.
	Robert G. Watson, Jr. Chief Executive Officer
	(Principal Financial Officer)
Date: August 12, 2013