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:
|
1.
|
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.
|
|
a.
|
convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and
|
|
b.
|
all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and
|
|
c.
|
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:
|
a.
|
be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,
|
|
b.
|
evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,
|
|
c.
|
bear interest from and after May 1, 2017, at a rate of 16.0% per annum,
|
|
d.
|
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
|
|
e.
|
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.
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:
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1.
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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.
|
|
a.
|
convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and
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b.
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all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and
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c.
|
retain our assets in Kansas and continue as a going concern. The Kansas assets currently provide most of our current operating
revenue.
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The restated secured note shall:
|
a.
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be secured by a first-priority lien in the Company’s
oil and gas producing assets situated in the State of Kansas,
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|
b.
|
evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,
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c.
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bear interest from and after May 1, 2017, at a rate of 16.0% per annum,
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d.
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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
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e.
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mature and be due and payable in full on November 1, 2017.
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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 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
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.
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:
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1.
|
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.
|
|
a.
|
convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and
|
|
b.
|
all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and
|
|
c.
|
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:
|
a.
|
be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,
|
|
b.
|
evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,
|
|
c.
|
bear interest from and after May 1, 2017, at a rate of 16.0% per annum,
|
|
d.
|
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
|
|
e.
|
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.
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
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. A Director of EnerJex Resources, Inc. is a co-guarantor
of bank debt held by Camber Energy, Inc.
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:
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•
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inability to attract and obtain additional development capital;
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•
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inability to achieve sufficient future sales levels or other operating results;
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•
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inability to efficiently manage our operations;
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•
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effect of our hedging strategies on our results of operations;
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•
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potential default under our secured obligations or material debt agreements;
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•
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estimated quantities and quality of oil reserves;
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•
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declining local, national and worldwide economic conditions;
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•
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fluctuations in the price of oil;
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•
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continued weather conditions that impact our abilities to efficiently manage our drilling and development activities;
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•
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the inability of management to effectively implement our strategies and business plans;
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•
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approval of certain parts of our operations by state regulators;
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•
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inability to hire or retain sufficient qualified operating field personnel;
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•
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increases in interest rates or our cost of borrowing;
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•
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deterioration in general or regional economic conditions;
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•
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adverse state or federal legislation or regulation that increases the costs of compliance, or adverse findings by a regulator
with respect to existing operations;
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•
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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;
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•
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inability to acquire mineral leases at a favorable economic value that will allow us to expand our development efforts;
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•
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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
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•
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changes in U.S. GAAP or in the legal, regulatory and legislative environments in the markets in which we operate.
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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 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 payments on April 6, 2016, and May 2, 2016. On April 7, 2016 the Company
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. The thirty day period will be used by the Company to pursue strategic alternatives.
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.
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:
|
1.
|
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.
|
|
a.
|
convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and
|
|
b.
|
all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and
|
|
c.
|
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:
|
a.
|
be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,
|
|
b.
|
evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,
|
|
c.
|
bear interest from and after May 1, 2017, at a rate of 16.0% per annum,
|
|
d.
|
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
|
|
e.
|
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.
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 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.
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:
|
1.
|
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.
|
|
a.
|
convey our oil and gas properties and associated performance and surety bonds in Colorado, Texas, and Nebraska, and
|
|
b.
|
all of our shares of Oakridge Energy, Inc. (together, the "conveyed oil and gas assets"); and
|
|
c.
|
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:
|
a.
|
be secured by a first-priority lien in the Company’s oil and gas producing assets situated in the State of Kansas,
|
|
b.
|
evidence accrued interest on the $4,500,000 principal balance at a rate of 16% per annum,
|
|
c.
|
bear interest from and after May 1, 2017, at a rate of 16.0% per annum,
|
|
d.
|
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
|
|
e.
|
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.
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.