10-Q 1 v465823_10q.htm FORM 10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended March 31, 2017

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 x 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 x No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer ¨		Accelerated filer ¨

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

		Emerging growth company ¨

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

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

Yes ¨ No x

The number of shares of Common Stock, $0.001 par value, outstanding on May 15, 2017 was 9,821,397 shares.

ENERJEX RESOURCES, INC.

FORM 10-Q

TABLE OF CONTENTS

		Page
PART I FINANCIAL STATEMENTS
ITEM 1.	FINANCIAL STATEMENTS	2
	Condensed Consolidated Balance Sheets at March 31, 2017 (unaudited) and December 31, 2016	2
	Condensed Consolidated Statements of Operations for the three months ended March 31, 2017 and 2016 (Unaudited)	3
	Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2017 and 2016 (Unaudited)	4
	Notes to Condensed Consolidated Financial Statements (Unaudited)	5
	FORWARD-LOOKING STATEMENTS	15
ITEM 2.	MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	17
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	29
ITEM 4.	CONTROLS AND PROCEDURES	29

PART II OTHER INFORMATION
ITEM 1.	LEGAL PROCEEDINGS	30
ITEM 1A.	RISK FACTORS	30
ITEM 2.	UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	30
ITEM 3.	DEFAULTS UPON SENIOR SECURITIES	30
ITEM 4.	MINE SAFETY DISCLOSURES	30
ITEM 5.	OTHER INFORMATION	31
ITEM 6.	EXHIBITS	31

SIGNATURES		34

PART 1 – FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

EnerJex Resources, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets

(Unaudited)

	March 31 ,			December 31,
	2017			2016
Assets
Current assets:
Cash unrestricted	$	140,360		$	128,035
Cash restricted		50,032			50,000
Accounts receivable		627,176			600,255
Derivative receivable		-			10,570
Inventory		201,675			185,733
Marketable securities		210,990			210,990
Deposits and prepaid expenses		376,251			493,384
Total current assets		1,606,484			1,678,967

Non-current assets:
Fixed assets, net of accumulated depreciation of $1,864,680 and $1,817,711		2,030,084			2,077,055
Oil and gas properties using full-cost accounting, net of accumulated DD&A of $15,266,692and $15,189,716		3,364,687			3,437,030
Other non-current assets		575,019			798,809
Total non-current assets		5,969,790			6,312,894
Total assets	$	7,576,274		$	7,991,861

Liabilities and Stockholders' Deficit
Current liabilities:
Accounts payable	$	836,785		$	294,241
Accrued liabilities		1,733,400			1,535,165
Current portion of long term debt		17,925,000			17,925,000
Total current liabilities		20,495,185			19,754,406

Asset retirement obligation		3,370,560			3,314,191
Other long-term liabilities		4,280,757			3,401,149
Total non-current liabilities		7,651,317			6,715,340
Total liabilities		28,146,502			26,469,746

Commitments & Contingencies
Stockholders' Deficit:
10% Series A Cumulative Perpetual Redeemable Preferred Stock, $0.001 par value, 25,000,000 shares authorized; 938,248 shares issued and outstanding at March 31, 2017 and December 31, 2016		938			938
Series B Convertible Preferred stock, $0.001 par value, 1,764 shares authorized, issued and outstanding at March 31, 2017 and December 31, 2016		2			2
Common stock, $0.001 par value, 250,000,000 shares authorized; shares issued and outstanding 8,423,936 at March 31, 2017 and December 31, 2016		8,424			8,424
Paid-in capital		69,114,589			69,090,613
Accumulated deficit		(89,694,181	)		(87,577,862	)
Total stockholder’s deficit		(20,570,228	)		(18,477,885	)
Total liabilities and stockholders' deficit	$	7,576,274		$	7,991,861

See Notes to Condensed Consolidated Financial Statements (unaudited).

EnerJex Resources, Inc. and Subsidiaries

Condensed Consolidated Statements of Operations

(Unaudited)

	For the Three Months Ended
	March 31,
	2017			2016

Revenues:
Oil revenues	$	609,504		$	533,973
Natural gas revenues		19,509			22,026
Total revenues		629,013			555,999

Expenses:
Direct operating costs		608,266			693,862
Depreciation, depletion and amortization		123,946			164,188
Impairment of oil and gas properties		-			4,506,933
Professional fees		310,264			77,809
Salaries		9,463			457,167
Administrative expense		133,955			183,706
Total expenses		1,185,894			6,083,665
Loss from operations		(556,881	)		(5,527,666	)

Other income (expense):
Interest expense		(679,840	)		(329,763	)
Derivative losses		-			(1,085,604	)
Other income		12			1,251,244
Total other (expense)		(679,828	)		(164,123
Net (loss)	$	(1,236,709	)	$	(5,691,789	)

Net (loss)		(1,236,709	)		(5,691,789	)
Preferred dividends		(879,607	)		(586,404	)
Net (loss) attributable to common stockholders	$	(2,116,316	)	$	(6,278,193	)
Net (loss) per share basic and diluted	$	(.25	)	$	(.75	)

Weighted average shares		8,423,936			8,423,936

See Notes to Condensed Consolidated Financial Statements (unaudited).

EnerJex Resources, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows

(Unaudited)

	For the Three Months Ended
	March 31,
	2017			2016
Cash flows from operating activities
Net loss	$	(1,236,709	)	$	(5,691,789	)
Depreciation, depletion and amortization		123,946			164,188
Impairment of oil and gas properties		-			4,506,933
Shares based payments issued for services		23,977			75,640
Accretion of asset retirement obligation		56,370			56,370
Gain derivatives		10,570			1,085,604
Settlement of asset retirement obligation		-			(2,767	)
Adjustments to reconcile net loss to cash (used in) provided by operating activities:
Accounts receivable		(26,921	)		88,569
Inventory		(15,942	)		(55,008	)
Deposits and prepaid expenses		117,133			(238,549	)
Accounts payable		542,544			(447,728	)
Accrued liabilities		198,234			(229,418	)
Cash flows (used in) operating activities		(206,798	)		(687,955	)

Cash flows from investing activities
Additions to oil and gas properties		(4,635	)		(7,597	)
Cash flows (used in) investing activities		(4,635	)		(7,597	)

Cash flows from financing activities
Repayment of long-term debt		-			(406,732	)
Deferred financing costs		223,790			30,108
Cash flows provided by (used in) financing activities		223,790			(376,624	)

Net increase (decrease) in cash		12,357			(1,072,176	)
Cash – beginning		178,035			3,101,682
Cash – ending	$	190,392		$	2,029,506

Supplemental disclosures:
Interest paid	$	-		$	299,968
Income taxes paid	$	-		$	-

Non-cash investing and financing activities:
Share based payments issued for services	$	23,977		$	75,640

See Notes to Condensed Consolidated Financial Statements (unaudited).

EnerJex Resources, Inc. and Subsidiaries

Notes to Condensed Consolidated Financial Statements (unaudited)

Note 1 – Basis of Presentation

The unaudited condensed consolidated financial statements of EnerJex Resources, Inc. (“we”, “us”, “our”, “EnerJex” and “Company”) 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, 2016.

Our consolidated financial statements include the accounts of our wholly-owned subsidiaries, EnerJex Kansas, Inc., Black Sable Energy, LLC, Working Interest, LLC and Black Raven Energy, Inc. for the three month period ended March 31, 2017 and for the year ended December 31, 2016. All intercompany transactions and accounts have been eliminated in consolidation.

Note 2 - Going Concern

The accompanying consolidated financial statements have been prepared assuming that the Company will continue as a going concern, which contemplates the realization of assets and liquidation of liabilities in the normal course of business. The Company had an accumulated deficit at March 31, 2017 of $89,694,181. Also, the net loss was $1,236,709 and cash used in operations was $206,798 for the three month period ended March 31, 2017. The ability of the Company to continue as a going concern is dependent upon its ability to successfully accomplish the plans described below to restructure, amend or refinance debt and secure financing and attain profitable operations. The accompanying consolidated financial statements do not include any adjustments that might be necessary if the Company is unable to continue as a going concern.

On October 3, 2011, the Company, entered into an Amended and Restated Credit Agreement with Texas Capital Bank, and other financial institutions and banks (“TCB” or “Bank”) that may become a party to the Credit Agreement from time to time. The facilities provided under the Amended and Restated Credit Agreement was to be used to refinance a prior outstanding revolving loan facility with TCB dated July 3, 2008, and for working capital and general corporate purposes. On August 15, 2014 the Company entered into an Eighth Amendment to the Amended and Restated Credit Agreement. Among other things the Eighth Amendment extended the maturity of the Agreement by three years to October 3, 2018. On August 12, 2015, the Company entered into a Tenth Amendment to the Amended and Restated Credit Agreement. Among other things the Tenth Amendment established the requirement of monthly borrowing base reductions commencing September 1, 2015 and continuing on the first of each month thereafter. On November 13, 2015, the Company entered into a Eleventh Amendment to the Amended and Restated Credit Agreement. The Eleventh Amendment reflects the following changes: (i) waived certain provisions of the Credit Agreement, (ii) suspend certain hedging requirements, and (iii) to make certain other amendments to the Credit Agreement.

On April 1, 2016 the Company informed the Bank that it would cease making the mandatory monthly borrowing base reduction payments and did not make the required April 1, 2016 payment. The Company made its mandatory quarterly interest payment on April 6, 2016 and on April 7, 2016 entered into a Forbearance Agreement whereby the Bank agreed to not exercise remedies and rights afforded it under the Amended and Restated Credit Agreement for thirty days. On May 31, 2016, the Company and the Bank amended to the Forbearance Agreement to extend the forbearance period to August 31, 2016. On July 29, 2016, the Company and the Bank entered into a Third Forbearance Agreement which extended the forbearance period to October 1, 2016. Upon the expiration of the Third Forbearance agreement, the Company did not enter into a fourth Forbearance Agreement. Also, at that time the Company discontinued payment of interest on its outstanding loan obligations with the Bank.

Throughout 2016, the Company evaluated plans to restructure, amend or refinance existing debt through private options. On February 14, 2017 the Company announced that a group of investors unrelated the Company has purchased from EnerJex’s secured bank lender all rights to the Company's secured indebtedness, and that EnerJex has executed with the purchasing investor group a definitive written agreement for the discharge of the Company's secured indebtedness.

On February 10, 2017, the Company, TCB and IberiaBank (collectively, "Sellers"), and PWCM Investment Company IC LLC, and certain financial institutions (collectively, "Buyers") entered into a Loan Sale Agreement ("LSA"), pursuant to which Seller sold to Buyers, and Buyers purchased from Sellers, all of Sellers' right, title and interest in, to and under the Credit Agreement and Loan Documents, in exchange for (i) a cash payment of $5,000,000 (the "Cash Purchase Price"), (ii) a Synthetic Equity Interest equal to 10% of the Proceeds, after Buyer's realization of 150% return on the Cash Purchase Price within five (5) years of the Closing Date, with payment being distributed 65.78947368% to TCB and 34.21052632% to IberiaBank, and (iii) at any time prior to February 10, 2022, Buyer may acquire the interest in clause (ii) above. In connection with the LSA, the Company release Sellers and its successors as holders of the rights under the Credit Agreement and Loan Documents, including Buyers, from any and all claims under the Credit Agreement and Loan Documents.

Also on February 10, 2017, the Company and its subsidiaries, and successor lender entered into a binding letter agreement dated February 10, 2017, which was subsequently amended on March 30, 2017 (as amended, the “letter agreement”) pursuant to which:

the successor lender would agree to forgive our existing secured loan in the approximate principal amount of $17,295,000, and in exchange enter into a secured promissory note (which we refer to as the "restated secured note") in the original principal amount of $4,500,000.

we would:

convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and

all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and

retain our assets in Kansas and continue as a going concern. The Kansas assets currently provide most of our current operating revenue.

The restated secured note shall:

be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,

evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,

bear interest from and after May 1, 2017, at a rate of 16.0% per annum,

be pre-payable in full at a discount at any time during the term of the restated secured note upon EnerJex's paying $3,300,000 to successor lender, and

mature and be due and payable in full on November 1, 2017.

We will have 2 options to extend the maturity date of the restated secured note by 90 days each upon payment of an extension fee of $100,000, which shall be applied against the principal balance of the note.

So long as we repay the $3,300,000 in indebtedness on or prior to the maturity date, as extended, all other amounts payable under the restated secured note shall be forgiven.

The Closing occurred on May 10, 2017.

Note 3 - Stock Options

A summary of stock options is as follows:

	Options			Weighted Avg. Exercise Price		Warrants		Weighted Avg. Exercise Price
Outstanding December 31, 2016		207,664		$	9.69		1,904,286	$	2.75
Granted		-			-		-		-
Cancelled		(50,000	)		-		-		-
Exercised		-			-		-		-
Outstanding March 31, 2017		157,664		$	9.69		1,904,286	$	2.75

Note 4 – 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.

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

	Fair Value Measurement
	Level 1		Level 2		Level 3
Marketable securities	$	-	$	-	$	210,990

Note 5 - Asset Retirement Obligation

Our asset retirement obligations relate to the liabilities associated with 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 obligations, December 31, 2016	$	3,314,191
Accretion		56,370
Asset retirement obligations, March 31, 2017	$	3,370,561

Note 6 - Long-Term Debt

Senior Secured Credit Facility

On October 3, 2011, the Company, 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 our option, loans under the facility 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).

We 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 Texas Capital Bank, which closed on December 15, 2011. The Amendment reflects the addition of Rantoul Partners, as an additional Borrower and adds as additional security for the loans the assets held by Rantoul Partners.

On August 31, 2012, we entered into a Second Amendment to Amended and Restated Credit Agreement with Texas Capital Bank. The Second Amendment: (i) increased the borrowing base to $7,000,000 (ii) reduced the minimum interest rate to 3.75% and (iii) added additional new leases as collateral for the loan.

On November 2, 2012, we entered into a Third Amendment to Amended and Restated Credit Agreement with Texas Capital Bank. The Third Amendment (i) increased the borrowing base to $12,150,000 and (ii) clarified certain continuing covenants and provided a limited waiver of compliance with one of the covenants so clarified for the fiscal quarter ended December 31, 2011.

On January 24, 2013, we 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) the Bank consented to the restructuring transactions related to the dissolution of Rantoul Partners, and (ii) the Bank terminated a Limited Guaranty, as defined in the Credit Agreement, executed by Rantoul Partners in favor of the Bank

On April 16, 2013, the Bank increased our borrowing base to $19.5 million.

On September 30, 2013, the Company entered into a Fifth Amendment to the Amended and Restated Credit Agreement. The Fifth Amendment reflects the following changes: (i) an expanded principal commitment amount of the Bank to $100,000,000; (ii) increased the Borrowing Base to $38,000,000; (iii) added Black Raven Energy, Inc. to the Credit Agreement as borrower parties; (iv) added certain collateral and security interests in favor of the Bank; and (v) reduced the Company’s current interest rate to 3.30%.

On November 19, 2013, we entered into a Sixth Amendment to the Amended and Restated Credit Agreement. The Sixth Amendment reflects the following changes: (i) the addition of Iberia Bank as a participant in our credit facility, and (ii) a technical correction to our covenant calculations.

On May 22, 2014, we entered into a Seventh Amendment to the Amended and Restated Credit Agreement. The Seventh Amendment reflects the Bank’s consent to our issuance of up to 850,000 shares of our 10% Series A Cumulative Redeemable Perpetual Preferred Stock.

On August 15, 2014 we entered into an Eighth Amendment to the Amended and Restated Credit Agreement. The Eighth Amendment reflects the following changes: (i) the borrowing base was increased from $38 million to $40 million, and (ii) the maturity of the facility was extended by three years to October 3, 2018.

On April 29, 2015, we entered into a Ninth Amendment to the Amended and Restated Credit Agreement. In the Ninth Amendment, the Banks (i) re-determined the Borrowing Base based upon the recent Reserve Report dated January 1, 2015, (ii) imposed affirmative obligations on the Company to use a portion of proceeds received with regard to future sales of securities or certain assets to repay the loan, (iii) consented to non-compliance by the Company with certain terms of the Credit Agreement, (iv) waived certain provisions of the Credit Agreement, and (v) agreed to certain other amendments to the Credit Agreement.

On May 1, 2015, the Borrowers and the Banks entered into a Letter Agreement to clarify that up to $1,000,000 in proceeds from any potential future securities offering will be unencumbered by the Banks’ Liens as described in the Credit Agreement through November 1, 2015, and that, until November 1, 2015, such proceeds shall not be subject to certain provisions in the Credit Agreement prohibiting the Company from declaring and paying dividends that may be due and payable to holders of securities issued in such potential offerings or issued prior to the Letter Agreement.

On August 12, 2015, we entered into a Tenth Amendment to the Amended and Restated Credit Agreement. The Tenth Amendment reflects the following changes: (i) allow the Company to sell certain oil assets in Kansas, (ii) allow for approximately $1,300,000 of the proceeds from the sale to be reinvested in Company owned oil and gas projects and (iii) apply not less than $1,500,000 from the proceed of the sale to outstanding loan balances.

On November 13, 2015, the Company entered into a Eleventh Amendment to the Amended and Restated Credit Agreement. The Eleventh Amendment reflects the following changes: (i) waived certain provisions of the Credit Agreement, (ii) suspend certain hedging requirements, and (iii) to make certain other amendments to the Credit Agreement.

On April 1, 2016 the Company informed the Bank that it would cease making the mandatory monthly borrowing base reduction payments and did not make the required April 1, 2016 payment. The Company made its mandatory quarterly interest payment on April 6, 2016 and on April 7, 2016 entered into a Forbearance Agreement whereby the Bank agreed to not exercise remedies and rights afforded it under the Amended and Restated Credit Agreement for thirty days. On May 31, 2016, the Company and the Bank amended the Forbearance Agreement to extend the forbearance period to August 31, 2016. On July 29, 2016, the Company and the Bank entered into a Third Forbearance Agreement which extended the forbearance period to October 1, 2016. Upon the expiration of the Third Forbearance agreement, the Company did not enter into a fourth Forbearance Agreement. Also, at that time the Company discontinued payment of interest on its outstanding loan obligations with the Bank.

On February 10, 2017, Borrowers, TCB and IberiaBank (collectively, "Sellers"), and PWCM Investment Company IC LLC, and certain financial institutions (collectively, "Buyers") entered into that certain Loan Sale Agreement ("LSA"), pursuant to which Seller sold to Buyers, and Buyers purchased from Sellers, all of Sellers' right, title and interest in, to and under the Credit Agreement and Loan Documents, in exchange for (i) a cash payment of $5,000,000 (the "Cash Purchase Price"), (ii) a Synthetic Equity Interest equal to 10% of the Proceeds, after Buyer's realization of 150% return on the Cash Purchase Price within five (5) years of the Closing Date, with payment being distributed 65.78947368% to TCB and 34.21052632% to IberiaBank, and (iii) at any time prior to the five (5) years of February 10, 2017, Buyer may acquire the interest in clause (ii) above. In connection with the LSA, Borrowers release Sellers and its successors as holders of the rights under the Credit Agreement and Loan Documents, including Buyers, from any and all claims under the Credit Agreement and Loan Documents.

we would:

convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and

all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and

retain our assets in Kansas and continue as a going concern. The Kansas assets currently provide most of our current operating revenue.

The restated secured note shall:

be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,

evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,

bear interest from and after May 1, 2017, at a rate of 16.0% per annum,

be pre-payable in full at a discount at any time during the term of the restated secured note upon EnerJex's paying $3,300,000 to successor lender, and

mature and be due and payable in full on November 1, 2017.

So long as we repay the $3,300,000 in indebtedness on or prior to the maturity date, as extended, all other amounts payable under the restated secured note shall be forgiven.

The Closing occurred on May 10, 2017.

Note 7 - Commitments & Contingencies

As of March 31, 2017 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.

Rent expense for the three months ended March 31, 2017 and 2016 was approximately $37,000 and $43,000 respectively. Future non-cancellable minimum lease payments are approximately $108,000 for the remainder of 2017, $91,000 for 2018 and $77,000 for 2019.

We, as a lessee and operator of oil and gas 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 and gas lease for the cost of pollution clean-up resulting from operations and subject to the lessee to liability for pollution damages. In some instances, the Company may be directed to suspend or cease operations in the affected area. As of March 31, 2017, we have no reserve for environmental remediation and are not aware of any environmental claims.

On September 23, 2016 the Company, American Standard Energy Corporation, Baylor Operating LLC, Bernard Given and Loeb & Loeb LLP were sued by Geronimo Holdings Corporation and Randal Capps in the 143rd Judicial District Court located in Pecos, Texas. The suit among other things, seeks damages for an alleged unlawful sale of properties in Crockett County Texas and for alleged unpaid royalties. The Company believes the suit is without merit and will vigorously defend itself. The Company has faith that it will prevail and at December 31, 2016 no reserve for potential losses arising from this matter has been recorded. Additionally under its agreement with Baylor Operating LLC, Baylor has agreed to indemnify and defend the Company against all lawsuits and claims including this one.

On April 26, 2016 C&F Ranch, LLC sued the Company in Allen County Kansas for alleged breach of contract related to the rental of certain lands located on the C&F Ranch. The Company believes that has paid all rents owe to C&F Ranch LLC and will vigorously defend itself. The Company has faith that it will prevail and at December 31, 2016 no reserve for potential losses arising from this matter has been recorded.

Note 8 - Impairment of Oil and Gas Properties

Pursuant to full cost accounting rules, the Company must perform a ceiling test each quarter on its proved oil and natural gas assets within each separate cost center. All of the Company’s costs are included in one cost center as all of the Company’s operations are located in the United States. The Company’s ceiling test was calculated using trailing twelve-month, unweighted-average first-day-of-the-month prices for oil and natural gas as of March 31, 2016, which were based on a West Texas Intermediate oil price of $45.16 per Bbl and a Henry Hub natural gas price of $2.40 per Mcf (adjusted for basis and quality differentials), respectively. This test resulted in a pre-tax write-down of $4,506,933 For the quarter ended March 31, 2017 the Company’s present value of future estimate cash flows discounted at 10% exceeded the net book value of those assets. Accordingly, the Company did not record an impairment charge.

Note 9 - Subsequent Events

we would:

convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and

all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and

retain our assets in Kansas and continue as a going concern. The Kansas assets currently provide most of our current operating revenue.

The restated secured note shall:

be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,

evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,

bear interest from and after May 1, 2017, at a rate of 16.0% per annum,

be pre-payable in full at a discount at any time during the term of the restated secured note upon EnerJex's paying $3,300,000 to successor lender, and

mature and be due and payable in full on November 1, 2017.

So long as we repay the $3,300,000 in indebtedness on or prior to the maturity date, as extended, all other amounts payable under the restated secured note shall be forgiven.

This transaction was approved by the Company’s shareholders at its annual meeting held on April 27, 2017.

The Closing occurred on May 10, 2017. At the Closing, in consideration of the satisfaction of $13,425,000 of the Company’s secured indebtedness, the Company and certain of the Subsidiaries transferred to PCR Holdings LLC, an affiliate of the successor lenders, all of the Company's oil and gas properties and assets located in Colorado, Texas, and Nebraska, as well as the Company's shares of Oakridge Energy, Inc.

To evidence the Company's remaining $4,500,000 of indebtedness to the Secured Lenders, the Subsidiaries entered into a Second Amended and Restated Credit Agreement with Cortland Capital Market Services LLC, as Administrative Agent, and the other financial institutions and banks parties thereto (the "Credit Agreement"), and a related Amended and Restated Note (the "Note"), pursuant to which the Company's and the Subsidiaries' obligations under the existing credit agreement were reduced to a principal amount of $4,500,000, with interest accruing thereon at 16% per annum. That Note matures on November 1, 2017 (subject to two 90-day extensions upon payment of a $100,000 fee for each extension). The debt is prepayable in full prior to maturity with a discounted payment of $3,300,000.

The Subsidiaries' obligations under the Credit Agreement and Note are non-recourse and are secured by a first-priority lien in the Company's and the Subsidiaries' oil properties and assets located in Kansas. The Company was removed as a borrower under the Credit Agreement, but entered into a Guaranty of Recourse Carveouts, pursuant to which the Company guarantees the Subsidiaries' payment of certain fees and expenses due under the Credit Agreement, and may be liable for certain conduct, such as fraud, bad faith, gross negligence, and waste of the Kansas oil properties or assets.

On April 27, 2017, the Company announced that it had entered into a definitive agreement with an institutional investor for an equity financing of up to $500,000. Under the terms of the agreement, EnerJex will initially issue 300 unregistered shares of its newly designated Series C Convertible Preferred Stock in exchange for $300,000. The investor shall have a right to purchase up to 200 additional unregistered preferred C shares within 12 months of the offering. The preferred stock will have a liquidation preference of $1,000 per share and will convertible at the option of the holder at a conversion price equal to $.30 per share. The preferred shares have no maturity date and may be redeemed by the Company 12 months after the closing or upon a change of control.

Additionally, effective May 1, 2017, the Company entered into an agreement with Camber Energy, Inc. pursuant to which EnerJex will be responsible for performing certain general and administrative services for Camber for a fee of $150,000 per month.

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

Note 10 – Related Party Transaction

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 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, 2016.

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., Black Sable Energy, LLC, Working Interest, LLC, and Black Raven Energy, Inc. unless the context requires otherwise. 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 Kansas, Colorado, Nebraska and Texas.

We continue to investigate multiple opportunities to both unlock value and accelerate growth in an accretive manner on behalf of shareholders, including but not limited to mergers, acquisitions, joint ventures, and non-dilutive financings. There can be no assurance of the results or timing associated with this process.

We have substantially curtailed capital spending in the current commodity price environment. Once the commodity market improves, we intend to focus our capital budget on the development of our Colorado and Kansas properties where we have identified hundreds of drilling locations and reactivation or recompletion opportunities that we believe will generate high rates of return with low risk profiles.

Recent Developments

The following is a brief description of our most significant corporate developments that have occurred since the end of 2016:

On April 28, 2016 the Bank informed the Company that it would extend the above Forbearance Agreement period to May 31, 2016 upon effecting a principal reduction of $125,000. In addition, the Company will receive an automatic extension to June 15, 2016 upon meeting certain terms and conditions specified by the Bank.

On October 1, 2016, the Company and TCB could not reach an agreement to extend the Third Amendment to the Forbearance Agreement. Following this outcome, the Company decided to discontinue payment of interest on its outstanding loan obligations with TCB. The Company continued to evaluate plans to restructure, amend or refinance existing debt through private options.

On October 26, 2016 the NYSE delisted our Series A preferred stock from the NYSE MKT due to the failure to maintain a market capitalization of above $1 million. On January 11, 2017, we announced that we received a letter of noncompliance from the NYSE by reason to hold an annual meeting for the fiscal year ended December 31, 2015. On January 17, 2017, we announced that the NYSE had accepted our plan to restore compliance with certain NYSE regulations on or before March 31, 2017. The NYSE has granted an extension due to the inability to complete this Annual Report on Form 10K in time to have a stockholder meeting by that date. The holding of this stockholder meeting is part of our plan to restore compliance.

we would:

convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and

all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and

retain our assets in Kansas and continue as a going concern. The Kansas assets currently provide most of our current operating revenue.

The restated secured note shall:

be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,

evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,

bear interest from and after May 1, 2017, at a rate of 16.0% per annum,

be pre-payable in full at a discount at any time during the term of the restated secured note upon EnerJex's paying $3,300,000 to successor lender, and

mature and be due and payable in full on November 1, 2017.

So long as we repay the $3,300,000 in indebtedness on or prior to the maturity date, as extended, all other amounts payable under the restated secured note shall be forgiven.

The Closing occurred on May 10, 2017.

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 three months ended March 31, 2017 and 2016.

	For the Three Months Ended
	March 31,
	2017		2016

Net Production
Oil (Bbl)		13,207		16,692
Natural gas (Mcf)		11,649		13,854

Average Sales Prices
Oil (per Bbl)	$	46.15	$	31.99
Natural gas (Mcf)	$	1.67	$	1.59

Average Production Cost (1)
Per Barrel of Oil Equivalent (“Boe”)	$	48.34	$	45.16

Average Lifting Costs (2)
Per Boe	$	40.16	$	36.52

⁽¹⁾

Production costs include all operating expenses, transportation 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 Three Months Ended March 31, 2017 and 2016 compared.

Income:

	Three Months Ended				Increase /
	March 31,				(Decrease)
	2017		2016
Oil revenues	$	609,504	$	533,973	$	(75,531	)
Natural gas revenues	$	19,509	$	22,026	$	(2,517	)

Oil Revenues

Oil revenues for the three months ended March 31, 2017 were $609,504 compared to revenues of $533,973 for the three months ended March 31, 2016. Of the revenue increase of $75,531 approximately $187,000 was due to higher crude oil prices. Crude oil prices increased $14.16 or 44% to an average price of $46.15 per barrel for the first three months of 2017 compared to $31.99 per barrel for the same period in 2016. Partially offsetting these increase, were lower production volumes. Revenues decreased approximately $111,500 as production decreased approximately 21% in the first three months of 2017 from 16,692 barrels produced in the first quarter of 2016 to 13,206 barrels produced for the three months ended March 31, 2017. The production decrease was due primarily to the curtailment of both growth and maintenance capital expenditures.

Natural Gas Revenues

Natural gas revenues for the three months ended March 31, 2017 was $19,509 compared to revenues of $22,026 for the three months ended March 31, 2016. Of the revenue decrease of $2,517 approximately $3,700 was due to lower production volumes. Production decreased in the first three months of 2017 from 13,854 mcf to11649 mcf for the comparable period of 2016. The production decrease was due primarily to the curtailment of both growth and maintenance capital expenditures. Partially offsetting this decrease was higher natural gas prices. Natural gas prices increased $.08 or 5% from an average price of $1.59 per mcf for the first three months of 2016 to an average price of $1.67 per mcf for the same period of 2017.

Expenses:

	Three Months Ended						Increase /
	March 31,						(Decrease)
	2017			2016
Production expenses:
Direct operating costs	$	608,266		$	693,862		$	(85,596	)
Depreciation, depletion and amortization		123,946			164,188			(40,242	)
Impairment of oil and gas properties		-			4,506,933			(4,506,933	)
Total production expenses		732,212			5,364,983			(4,632,771	)

General expenses:
Professional fees		310,264			77,809			232,455
Salaries		9,463			457,167			(447,704	)
Administrative expense		133,955			183,706			(49,751	)
Total general expenses		453,682			718,682			(265,000	)
Total production and general expenses		1,185,894			6,083,665			(4,897,771	)

Loss from operations		(556,881	)		(5,527,666	)		(4,970,785	)

Other income (expense)
Interest expense		(679,840	)		(329,763	)		(350,077	)
Derivative losses		-			(1,085,604	)		1,085,604
Other income		12			1,251,244			(1,251,232	)
Total other income (expense)		(679,828	)		(164,123			(515,705	)

Net loss	$	(1,236,709	)	$	(5,691,789	)	$	(4,455,080	)

Direct Operating Costs

Direct operating costs include direct labor and equipment costs related to pumping, gauging, pulling, well repairs, compression, transportation costs, and general maintenance requirements in our oil and gas fields. These costs also include certain contract labor costs, and other non-capitalized expenses. Direct operating costs for the three months ended March 31, 2017 decreased $85,596, or 12% to $608,266 from $693,862 for the three months ended March 31, 2016. Direct operating costs per boe increased $3.64 or approximately 10% in 2017 compared to 2016 at $40.16 per boe and $36.52 per boe respectively.

Depreciation, Depletion and Amortization

Depreciation, depletion and amortization for the three months ended March 31, 2017 was $123,946 compared to $164,188 for the three months ended March 31, 2016. The decrease in depletion expense of approximately $40,200 or approximately 24% was due to lower per boe depletion rates in 2017 compared to 2016, as well as lower overall production in 2017. The lower depletion rate resulted primarily from the write-down of oil and gas properties mandated by the Securities and Exchange Commission’s Full Cost Ceiling Test rules (see footnote 9 to the financial statements for a full explanation of the Ceiling Test). Depletion expense per boe decreased $1.71 or approximately 25% in the first quarter of 2017 compared to the first quarter of 2016 and as also discussed above production decreased approximately 21% quarter over quarter due primarily to lower spending on lease operating expenditures and lower investments in maintenance capital.

Impairment of Oil and Gas Properties

Under the full cost method of accounting, capitalized oil and gas property costs less accumulated depletion and net of deferred income taxes may not exceed an amount equal to the sum of the present value, discounted at 10%, of estimated future net revenues from proved oil and gas reserves and the cost of unproved properties not subject to amortization (without regard to estimates of fair value), or estimated fair value, if lower, of unproved properties that are not subject to amortization. Should capitalized costs exceed this ceiling, an impairment expense is recognized.

For the three months ended March 31, 2017, we were not required to record an impairment expense on our evaluated oil and gas properties compared to a charge of $4,506,933 for the three months ended March 31, 2016.

Professional Fees

Professional fees for the three months ended March 31, 2017 were $310,264 compared to $77,809 for the three months ended March 31, 2016. The increase in professional fees of approximately $232,455 was due primarily to increased spending in 2017 on investor relations services ($2,100), financial and tax consulting ($123,900), legal expenditures incurred with outside attorneys ($79,000) and external auditors ($28,500). These increase were partially offset by decreased spending for engineering and other consulting services

Salaries

Salaries for the three months ended March 31, 2017 were $9,463 compared to $457,167 for the three months ended March 31, 2016. The decrease in salaries of $447,704 was due primarily to the resignation of the CEO and CFO in the first quarter and third party payments to the Company for the use of accounting and administrative staff.

Administrative Expenses

Administrative expenses for the three months ended March 31, 2017 were $133,955 compared to $183,706 for the three months ended March 31, 2016. The decrease of approximately $49,700 in 2017 was due primarily to lower insurance, SEC costs, rents and office supplies. These decrease were partially offset by higher meal and travel costs and lower G&A expense reimbursements from a working interest partner.

Interest Expense

Interest expense for the three months ended March 31, 2017 was $679,840 compared to $329,763 for the three months ended March 31, 2016 an increase of approximately $350,000. Interest expense increased as a result of higher interest rates charge under the forbearance agreement and subsequently by the Buyers of the outstanding debt on February 10, 2017(see note 9 to the financial statements for further information).

(Loss) on Derivatives Contracts

All of the Company’s hedge contract expired in 2016, so we incurred no unrealized gains or losses in the first quarter of 2017. We incurred an unrealized loss of $1,085,604 in the first quarter of 2016 due to the marking to market of our derivative contracts.

Other Income

Other income decreased approximately $1,250,000 in the first quarter of 2017 from $1,251,244 in 2016 to $12 in 2017. The decrease was due to the expiration of derivative contracts in 2016, resulting in no realization of gains from their monetization in 2017.

Net (Loss)

The net loss for the three months ended March 31, 2017 was $1,236,709 compared to a net loss of $5,691,789 for the three months ended March 31, 2016. The decrease in the net loss was due primarily to the reduction in the impairment of oil and gas properties of $4,506,933.

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, asset sales, and the issuance of equity securities. Due to the decline in oil prices, the resulting decline in our reserves as reflected in our reserve report which caused a corresponding reduction in our borrowing base, and the recent issuances of equity securities from our "shelf" registration, it will be more difficult in 2017 to use our historical means of meeting our capital requirements to provide us with adequate liquidity to fund our operations and capital program.

The following table summarizes total current assets, total current liabilities and working capital.

	March 31, 2017			December 31 , 2016			Increase / (Decrease)

Current Assets	$	1,606,484		$	1,678,967		$	(72,483	)

Current Liabilities	$	20,495,185		$	19,754,406		$	740,779

Working Capital	$	(18,888,701	)	$	(18,075,439	)	$	(813,262	)

Senior Secured Credit Facility

On April 16, 2013, the Bank increased our borrowing base to $19.5 million.

On April 1, 2016 the Company informed the Bank that it would cease making the mandatory monthly borrowing base reduction payments and did not make the required April 1, 2016 payment. The Company made its mandatory quarterly interest payment on April 6, 2016 and on April 7, 2016 entered into a Forbearance Agreement whereby the Bank agreed to not exercise remedies and rights afforded it under the Amended and Restated Credit Agreement for thirty days. On May 31, 2016, the Company and the Bank amended the Forbearance Agreement to extend the forbearance period to August 31, 2016. On July 29, 2016, the Company and the Bank entered into a Third Forbearance Agreement which extended the forbearance period to October 1, 2016. Upon the expiration of the Third Forbearance agreement, the Company did not enter into a fourth Forbearance Agreement. Also, at that time the Company discontinued payment of interest on its outstanding loan obligations with the Bank.

we would:

convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and

all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and

retain our assets in Kansas and continue as a going concern. The Kansas assets currently provide most of our current operating revenue.

The restated secured note shall:

be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,

evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,

bear interest from and after May 1, 2017, at a rate of 16.0% per annum,

be pre-payable in full at a discount at any time during the term of the restated secured note upon EnerJex's paying $3,300,000 to successor lender, and

mature and be due and payable in full on November 1, 2017.

So long as we repay the $3,300,000 in indebtedness on or prior to the maturity date, as extended, all other amounts payable under the restated secured note shall be forgiven.

The Closing occurred on May 10, 2017.

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

At March 31, 2017 we had 10 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 of our oil and gas properties, asset retirement obligations, and share-based payments.

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 costs related to production, general corporate overhead or similar activities.

Proved properties are amortized using the units of production (UOP) method. Currently we only have operations in the Unites States of America. The UOP calculation multiplies the percentage of estimated proved reserves produced each quarter by the cost of these reserves. The amortization base in the UOP calculation includes the sum of proved property, net of accumulated depreciation, depletion and amortization (DD&A), estimated future development costs (future costs to access and develop proved reserves) and asset retirement costs, less related salvage value.

The cost of unproved properties are excluded from the amortization calculation until it is determined whether or not proved reserves can be assigned to such properties or until development projects are placed into service. Geological and geophysical costs not associated with specific properties are recorded as proved property immediately. Unproved properties are reviewed for impairment quarterly.

Under the full cost method of accounting, the net book value of oil and gas properties, less deferred income taxes, may not exceed a calculated “ceiling.” The ceiling limitation is (a) the present value of future net revenues computed by applying current prices of oil & gas reserves (with consideration of price changes only to the extent provided by contractual arrangements) to estimated future production of proved oil & gas reserves as of the date of the latest balance sheet presented, less estimated future expenditures (based on current costs) to be incurred in developing and producing the proved reserves computed using a discount factor of 10 percent and assuming continuation of existing economic conditions plus (b) the cost of properties not being amortized plus (c) the lower of cost or estimated fair value of unproven properties included in the costs being amortized less (d) income tax effects related to differences between book and tax basis of properties. Future cash outflows associated with settling accrued retirement obligations are excluded from the calculation. Estimated future cash flows are calculated using end-of-period costs and an unweighted arithmetic average of commodity prices in effect on the first day of each of the previous 12 months held flat for the life of the production, except where prices are defined by contractual arrangements.

Any excess of the net book value of proved oil and gas properties, less related deferred income taxes, over the ceiling is charged to expense and reflected as additional DD&A in the statement of operations. The ceiling calculation is performed quarterly. For the quarter ended March 31, 2017, no impairment charges were required and for the quarter ended March 31, 2016 our impairment charge was $4,506,933.

Asset Retirement Obligations

The asset retirement obligation relates to the plugging 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 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.

Louis G. Schott our chief executive officer and Douglas M. Wright our chief financial officer, 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 pursuant to Exchange Act Rule 13-a-15(b). Based on the evaluation, Mr. Schott concluded that our disclosure controls and procedures are effective.

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, except the legal proceedings discussed below.

ITEM 1A. RISK FACTORS

In addition to the risk factors below and the other information set forth in this report, you should carefully consider the factors discussed in Part I, "Item 1A. Risk Factors" in our 2016 Annual Report on Form 10-K filed on March 31, 2017, which could materially affect our business, financial condition or future results. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also materially affect our business, financial condition or future results.

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

None.

ITEM 3. DEFAULTS UPON SENIOR SECURITIES.

None.

ITEM 4. MINE SAFETY DISCLOSURES.

Not applicable.

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).
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 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 Appendix C to Schedule 14A, filed on September 6, 2013)
3.3		Certificate of Amendment of Articles of Incorporation as filed with the Nevada Secretary of State on May 29, 2014 (incorporated by reference as Exhibit 3.1 on Current Report Form 8-K filed on May 29, 2014)
3.4		Certificate of Amendment of Articles of Incorporation (incorporated by reference as Exhibit 3.1 on Current Report Form 8-K filed on May 29, 2014)
3.5		Amended and Restated Certificate of Designation for Series A Preferred Stock (incorporated by reference to Exhibit 4.6 to the Form S-1/A filed on September 3, 2014)
3.6		Certificate of Designation of Preferences, Rights and Limitations of Series B Convertible Preferred Stock (incorporated by reference as Exhibit 4.1 on Current Report Form 8-K filed on March 11, 2015)
4.1		Specimen common stock certificate (incorporated by reference to Exhibit 4.3 to the Form S-1/A filed on May 27, 2008)
4.2		Specimen Series A Preferred Stock Certificate (incorporated by reference to Exhibit 4.4 to the Form S-1/A filed on September 3, 2014)
4.3		Specimen Series B Convertible Preferred Stock Certificate (incorporated by reference as Exhibit 4.2 on Current Report Form 8-K filed on March 11, 2015)
4.4		Certificate of Designation for Series A Preferred Stock (incorporated by reference to Exhibit 4.1 to the Form 8-K filed on January 6, 2011).
4.5		Form of Warrant to Purchase Common Stock (incorporated by reference as Exhibit 4.3 on Current Report Form 8-K filed on March 11, 2015)
4.6		Form of Placement Agent Warrant (incorporated by reference as Exhibit 4.4 on Current Report Form 8-K filed on March 11, 2015)
10.1		Form of Officer and Director Indemnification Agreement (incorporated by reference to Exhibit 10.2 to the Form 8-K filed on October 16, 2008)
10.2		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)
10.3		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)
10.4		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)
10.5		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)
10.6		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).
10.7		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).

10.8		Amended and Restated Credit Agreement dated October 3, 2011 (incorporated by reference to Exhibit 10.1 on Form 8-K filed on October 6, 2011).
10.9		Option and Joint Development Agreement by and among Registrant and MorMeg, LLC dated August 2011 (incorporated by reference to Exhibit 10.1 on Form 8-K filed on November 15, 2011).
10.10		First Amendment to Amended and Restated Credit Agreement dated December 14, 2011 (incorporated by reference to Exhibit 10.2 on Form 8-K filed on December 14, 2011).
10.11		Second Amendment to Amended and Restated Credit Agreement dated August 31, 2012 (incorporated by reference to Exhibit 10.1 on Form 8-K filed on November 8, 2012).
10.12		Third Amendment to Amended and Restated Credit Agreement dated November 2, 2012 (incorporated by reference to Exhibit 10.2 on Form 8-K filed on November 8, 2012).
10.13		Amended and Restated Employment Agreement by and among Registrant and Robert G. Watson, Jr. dated December 31, 2012 (incorporated by reference to Exhibit 10.1 on Form 8-K filed on January 4, 2013).
10.14		Fourth Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank dated December 31, 2012 (incorporated by reference to Exhibit 10.2 on Form 8-K filed on January 30, 2013).
10.15		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 by reference to Exhibit 10.3 on Form 8-K filed on January 30, 2013).
10.16		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 by reference to Exhibit 10.4 on Form 8-K filed on January 30, 2013).
10.17		2013 Stock Incentive Plan (incorporated by reference to Exhibit 10.1 on Registration Statement on Form S-8 filed on September 12, 2013).
10.18		Fifth Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank, N.A. dated September 30, 2013 (incorporated by reference to Exhibit 10.1 on Form 8-K filed October 1, 2013).
10.19		Nineth Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank, N.A. dated November 19, 2013 (incorporated by reference to Exhibit 10.37 on Form 10-Q filed May 13, 2014).
10.20		Exchange Agreement between EnerJex Resources, Inc. and holders of Series A preferred stock (incorporated by reference to Exhibit 10.38 on Form S-1/A Amendment No. 2 filed September 3, 2014).
10.21		Seventh Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank, N.A. dated May 22, 2014 (incorporated by reference to Exhibit 10.1 to Form 8-K filed May 27, 2014).
10.22		Form of Securities Purchase Agreement dated as of March 11, 2015 (incorporated by reference as Exhibit 10.1 on Current Report Form 8-K filed on March 11, 2015)
10.23		Eighth Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank, N.A. dated August 13, 2014 (incorporated by reference as Exhibit 10.23 on Form 10-K filed March 31, 2015).
10.24		Ninth Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank, N.A. dated April 29, 2015 (incorporated by reference to Exhibit 10.1 to Form 8-K filed May 5, 2015).
10.25		Purchase Agreement by and among Registrant and Northland Securities, Inc. dated May 8, 2015(incorporated by reference as Exhibit 1.1 of Form 8-K filed May 8, 2015.)
10.26		Tenth Amendment to the Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank, N.A. dated September 8, 2015 (incorporated by reference to Exhibit 10.26 of Form 10-Q filed November 16, 2015).
10.27		Eleventh Amendment to Amended and Restated Credit Agreement by and among Registrant and Texas Capital Bank, N.A. dated November 16, 2015 (incorporated by reference to Exhibit 10.1 to Form 8-K filed November 16, 2015).

10.28		Forbearance Agreement dated April 4, 2016 (incorporated by reference to Exhibit 10.28 to Form 10-K filed April 11, 2016).
10.29		Third Amendment to Forbearance Agreement dated July 29, 2016 (incorporated by reference to Exhibit 10.1 to Form 8-K filed on August 1, 2016.
10.30		Letter Agreement dated February 10, 2017, by and among Texas Capital Bank, N.A., Iberia Bank, PWCM Investment Company IC LLC, EnerJex Resources, Inc., EnerJex Kansas, Inc., Black Sable Energy, LLC, Black Raven Energy, Inc. and Adena, LLC (incorporated by reference to Exhibit 10.1 on Form 8-K filed February 14, 2017).
10.31		Loan Sale Agreement dated February 10, 2017, by and among Texas Capital Bank, N.A., Iberia Bank, PWCM Investment Company IC LLC, EnerJex Resources, Inc., EnerJex Kansas, Inc., Black Sable Energy, LLC, Black Raven Energy, Inc., and Adena, LLC (incorporated by reference to Exhibit 10.2 on Form 8-K filed February 14, 2017).
10.32		Consulting Agreement dated February 10, 2017, by and between Registrant and Douglas Wright (incorporated by reference to Exhibit 10.3 on Form 8-K filed February 14, 2017).
10.33		Employment Agreement dated February 10, 2017, by and between Registrant and Louis G. Schott (incorporated by reference to Exhibit 10.4 on Form 8-K filed February 14, 2017).
10.34		Separation and General Release Agreement dated February 10, 2017, by and between Registrant and Robert G. Watson, Jr. (incorporated by reference to Exhibit 10.34 on Form 10-K filed March 31, 2017)
21.1		Subsidiaries(incorporated by reference to Exhibit 21.1 on Form 10-K filed March 31, 2017)
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*

101.INS		XBRL Instance Document*
101.SCH		XBRL Taxonomy Extension Schema Document*
101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document*
101.DEF		XBRL Taxonomy Extension Definition Linkbase Document*
101.LAB		XBRL Taxonomy Extension Label Linkbase Document*
101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document*

* Filed herewith.

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/ Louis G. Schott
	Louis G. Schott Interim Chief Executive Officer

Date: May 15, 2017