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, and incorporated by reference in, 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 and other opportunities in Oklahoma 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 because of the current commodity price environment and the Company’s limited capital. Once the commodity market and/or capital availability improves, we intend to focus our budget on the development of our Kansas properties where we have identified certain drilling locations and reactivation or recompletion opportunities that we believe will generate high rates of return with low risk profiles as well as certain acquisitions.

Plan of Operations

The Board of Directors is currently pursuing possible strategic transactions involving opportunities both in and outside the oil and gas industry that will offer the opportunity for future growth and net cash flow. Those opportunities may involve a business combination with another business enterprise, the acquisition of one or more groups of assets, an equity or debt financing transaction to provide capital with which to fund operations and expansion, and other similar transactions. To illustrate the types of transactions that the Company is investigating, the Company has been investigating the acquisition by purchase or contribution of certain operating oil and gas assets. In addition, the Company recently was involved in discussions about a possible acquisition by merger of a privately held company that operates an agricultural drone business and in which an affiliate of the holder of the Company’s Series B Preferred Stock has an interest. While the discussions about a business combination with that privately held agricultural drone enterprise have been suspended, those discussions may resume in the future. In addition, the Company expects to continue to pursue other acquisition and business combination opportunities. No assurance can be given that any one or more of these potential business combinations or asset acquisition opportunities will be consummated.

Recent Developments

The following is a brief description of our most significant corporate developments that have occurred since the end of 2015:

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.

On October 1, 2016, the Company and the Bank 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 the Bank. The Company continued to evaluate plans to restructure, amend or refinance existing debt through private options.

On October 26, 2016, the NYSE MKT (the “ NYSE ”) delisted our Series A preferred stock from the NYSE 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 due to our failure 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 subsequently granted an extension and on April 27, 2017, the Company held an annual meeting of shareholders.

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 restated secured note:

We will have two options to extend the maturity date of the restated secured note by 90 days each (first to January 30, 2018 and then to April 30, 2018), upon payment of extension fees of $100,000 for each extension.

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 are to be forgiven.

The closing occurred on May 10, 2017. As part of the closing procedures and net settlement, we issued a promissory note to Pass Creek Resources LLC in the amount of $105,806. The promissory bears interest at 16% per annum and matured on June 9, 2017. The amount due was not paid on June 9, 2017, but the holder has not provided the Company a notice of default. As of June 30, 2017, the principal balance of $105,806 along with accrued interest remained due.

In connection with the May 10, 2017 closing and in consideration of the satisfaction of $13,425,000 of the amount due under the Credit Agreement, as amended, the Company and certain of its subsidiaries transferred to PCR Holdings LLC, an affiliate of the successor lenders under the Credit Agreement, 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 PWCM Investment Company IC LLC (“ PWCM ”), RES Investment Group, LLC (“ RES ”), Round Rock Development Partners, LP (“ Round Rock ”), and Cibolo Holdings, LLC (“ Cibolo Holdings, ” and together with PWCM, RES and Round Rock, “ Successor Lenders ”), the Company’s subsidiaries (except Kansas Holdings, LLC) 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 “ New Credit Agreement ”), and a related Amended and Restated Note (the “ New Note ”), in the amount of $3.3 million as described above.

Our 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.

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 and six month periods ended June 30, 2017 and 2016.

Results of Operations for the Three and Six Months Ended June 30, 2017 and 2016 compared.

Oil Revenues

Oil revenues for the six months ended June 30, 2017, were $895,195 compared to revenues of $1,127,147 for the six months ended June 30, 2016 and for the three months ended June 30, 2017, were $285,691 compared to revenues of $593,174 for the same period in 2016. Of the year-to-date oil revenue decrease of $231,952, approximately $509,000 (offset by the increase in prices as described below) was due to lower production volumes. Oil production decreased approximately 36% in the first six months of 2017 from 30,911 barrels produced in the first half of 2016 to 19,633 barrels produced for the first six months ended June 30, 2017. The production decrease was due primarily to the curtailment of both growth and maintenance capital expenditures, and the conveyance of the Company’s oil and gas properties in Colorado, Nebraska and Texas in connection with the restructuring of its outstanding senior debt in May 2017.

This was offset by an increase in revenues of approximately $277,000 due to higher crude oil prices. Crude oil prices increased $8.96 or 25% to an average price of $45.42 per barrel for the first six months of 2017 compared to $36.46 per barrel for the same period in 2016.

Natural Gas Revenues

Natural gas revenues for the six months ended June 30, 2017 were $19,509 compared to revenues of $24,532 for the six months ended June 30, 2016 and for the three months ended June 30, 2017 were $0 compared to revenues of $2,506 for the same period in 2016. Of the year-to-date revenue decrease of $5,023, approximately $27,000 (offset by the increase in prices as described below) was due to lower production volumes. Production decreased in the first six months of 2017 from 27,515 Mcf for the six months ended June 30, 2016, to 11,649 Mcf for the comparable period of 2017. The production decrease was due primarily to the curtailment of both growth and maintenance capital expenditures and the conveyance of the Company’s oil and gas properties in Colorado, Nebraska and Texas in connection with the restructuring of its outstanding senior debt in May 2017. This was offset by an increase in revenues of approximately $22,000 due to higher natural gas prices. Natural gas prices increased $0.78 or 88% from an average price of $0.89 per Mcf for the first six months of 2016 to an average price of $1.67 per Mcf for the same period of 2017.

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 six months ended June 30, 2017 decreased by $539,529, or 40% to $808,136 from $1,347,665 for the six months ended June 30, 2016 and for the three months ended June 30, 2017 were $199,870 compared to $653,803 for the same period in 2016. Year-to-date direct operating costs per Boe decreased $0.64 or approximately 2% to $37.33 for 2017, compared to $37.97 per boe for the same period of 2016. The decrease was primarily due to the curtailment of both growth and maintenance capital expenditures, and the conveyance of the Company’s oil and gas properties in Colorado, Nebraska and Texas.

Depreciation, Depletion and Amortization

Depreciation, depletion and amortization for the six months ended June 30, 2017 was $225,235 compared to $248,678 for the six months ended June 30, 2016 and for the three months ended June 30, 2017 was $101,289 compared to $84,490 for the same period in 2016. The year-to-date decrease in depletion expense of $23,443 or approximately 9% was due to the decrease in our depletable base year-over-year resulting from the impairment sustained in 2016 and further reduced by lower production volumes. Depletion expense per Boe decreased $3.40 or approximately 49% in the first half of 2017 compared to the first half of 2016 and also as discussed above production decreased approximately 39% six months over six months 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 and six months ended June 30, 2017, we were not required to record an impairment expense on our evaluated oil and gas properties. For the three and six months ended June 30, 2016, we recognized an impairment expense on our evaluated oil and gas properties of $2,137,663 and $6,644,596, respectively.

Professional Fees

Professional fees for the six months ended June 30, 2017 were $422,538 compared to $137,117 for the six months ended June 30, 2016 and $112,275 for the three months ended June 30, 2017 compared to $59,308 for the same period in 2016. The increase in year-to-date professional fees of $285,421 was due primarily to increased spending in 2017 on consulting, legal, and investor relations services. These increases were partially offset by decreased third party reserve engineering fees.

Salaries

Salaries for the six months ended June 30, 2017 were $277,147 compared to $810,059 for the six months ended June 30, 2016 and $267,684 for the three months ended June 30, 2017 compared to $326,312 for the same period in 2016. The decrease in year-to-date salaries of approximately $532,912 is due primarily to a reduced number of employees.

Administrative Expenses

Administrative expenses for the six months ended June 30, 2017 were $271,036 compared to $248,862 for the six months ended June 30, 2016 and $137,081 for the three months ended June 30, 2017 compared to $91,736 for the same period in 2016. The year-to-date increase of approximately $22,174 in 2017 compared to 2016, was due primarily to increased general and administrative from a working interest partner, IT, telecom, software, and meals, travel, and entertainment. The increase was partially offset by higher SEC reporting costs, taxes and other, training, and dues and subscriptions.

Interest Expense

Interest expense for the six months ended June 30, 2017 was $724,494 compared to $662,219 for the six months ended June 30, 2016, an increase of approximately $62,275 and $44,654 for the three months ended June 30, 2017 compared to $332,456 for the same period in 2016. Interest expense increased as a result of higher interest rate charges under the forbearance agreement offset by the reduction of debt under the Loan Sale Agreement (“ LSA ”) (see note 2 to the financial statements for further information).

Gain on Loan Sale Agreement

For the three and six months ended June 30, 2017, we recognized a gain of $11,500,124 on the LSA and the restructuring of our debt completed thereby. For the three and six months ended June 30, 2016, we had no loan sale gains or sale of loans.

Loss on Derivatives

All of the Company’s hedge contracts expired in 2016, so we incurred no unrealized gains or losses in the six month ended June 2017. We recorded an unrealized loss of $2,381,396 in the marking to market of our derivative contracts for the first six months of 2016 and $1,295,792 for the three months ended June 30, 2016.

Other Income

Other income decreased by $1,927,340 in 2017 from $2,174,186 for the six months ended June 30, 2016 to $246,846 for the six months ended June 30, 2017 and decreased by $676,109 for the three months ended June 30, 2017 compared to the same period in 2016. The decrease was due to the expiration of derivative contracts in 2016, resulting in no realization of gains from their monetization in 2017 offset by income from performing certain general and administrative services for Camber Energy, Inc., for a fee of $150,000 per month beginning May 2017.

Net Income (Loss)

The net income for the six months ended June 30, 2017 was $9,933,088 compared to a net loss of $9,154,727 for the six months ended June 30, 2016 and net income of $11,169,795 for the three months ended June 30, 2017, compared to net loss of $3,462,938 for the same period in 2016. The year-to-date increase in the net income was due primarily to the gain from the LSA of $11,500,124 and the reduction in the impairment of oil and gas properties of $6,644,596.

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 and the restructuring of our outstanding debt, it will be more difficult during the remainder of 2017 and into 2018 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.

The working capital deficit at June 30, 2017 was $4,744,155 compared to $18,075,439 at December 31, 2016. The year-to-date decrease in the working capital deficit was primarily due to the $13.5 million of debt forgiven as part of the LSA.

We had $532,526 of cash used in operating activities for the six months ended June 30, 2017, which was mainly due to $11.0 million of gain on the LSA, offset by the $9.9 million net income for the period.

We had $4,635 of cash used in investing activities for the six months ended June 30, 2017, which was solely due to the purchase of oil and gas properties.

We had $450,000 of cash provided by financing activities for the six months ended June 30, 2017, which was due to proceeds from the sale of Series C Convertible Preferred Stock ($450,000).

The unaudited condensed consolidated financial statements included in Part I Financial Information, Item 1 Financial Statements, of this report have been prepared assuming that the Company will continue as a going concern. There is currently substantial doubt about the Company’s ability to continue as a going concern as discussed in Note 1 to the unaudited condensed consolidated financial statements.

The Company’s Senior Secured Credit Facility is described below. Note 6 to the unaudited condensed consolidated financial statements includes additional information on certain commitments and contingencies of the Company.

Senior Secured Credit Facility

On October 3, 2011, the Company and DD Energy, Inc., EnerJex Kansas, Inc., Black Sable Energy, LLC and Working Interest, LLC, its subsidiaries (“ Borrowers ”) entered into an Amended and Restated Credit Agreement with Texas Capital Bank, N.A. (the “ 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 were used to refinance Borrowers’ prior outstanding revolving loan facility with Bank, dated July 3, 2008, and for working capital and general corporate purposes.

At our option, loans under the facility will bear stated interest based on the Base Rate plus Base Rate Margin, or Floating Rate plus Floating Rate Margin (as those terms are defined in the Credit Agreement). The Base Rate will be, 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 nine 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).

On December 15, 2011, 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 the Bank, which closed on December 15, 2011. The Amendment reflected the addition of Rantoul Partners as an additional Borrower and added as additional security for the loans the assets held by Rantoul Partners.

On August 31, 2012, we entered into a Second Amendment to Amended and Restated Credit Agreement with the Bank. The Second Amendment: (i) increased our 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 the Bank. The Third Amendment (i) increased our 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 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 the Bank. The Fourth Amendment reflected 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, we entered into a Fifth Amendment to the Amended and Restated Credit Agreement. The Fifth Amendment reflected the following changes: (i) an expanded principal commitment amount of the Bank to $100,000,000, (ii) an increase in our Borrowing Base to $38,000,000, (iii) the addition of Black Raven Energy, Inc., our wholly-owned subsidiary, to the Credit Agreement as a borrower party, (iv) the addition of certain collateral and security interests in favor of the Bank, and (v) the reduction of our 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 reflected the following changes: (i) the addition of Iberia Bank as a participant in our credit facility (together with the Bank, the “ Banks ”), 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 reflected the Bank’s consent to our issuance of up to 850,000 shares of our 10% Series A Cumulative Perpetual Preferred Stock.

On August 15, 2014, we entered into an Eighth Amendment to the Amended and Restated Credit Agreement. The Eighth Amendment reflected 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 our 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 would 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 reflected the following changes, it: (i) allowed the Company to sell certain oil assets in Kansas, (ii) allowed for approximately $1,300,000 of the proceeds from the sale to be reinvested in Company owned oil and gas projects, and (iii) provided that not less than $1,500,000 from the proceed of the sale would be applied to outstanding loan balances.

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

On April 1, 2016, the Company informed the Banks 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 Banks 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 Banks amended the Forbearance Agreement to extend the forbearance period to August 31, 2016. On July 29, 2016, the Company and the Banks 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 Banks.

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 a 150% return on the Cash Purchase Price within five (5) years of the closing date of the sale, 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 released 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 restated secured note:

We will have two options to extend the maturity date of the restated secured note by 90 days each (first to January 30, 2018 and then to April 30, 2018), upon payment of extension fees of $100,000 for each extension.

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 are to be forgiven.

The closing occurred on May 10, 2017. As part of the closing procedures and net settlement, we issued a promissory note to Pass Creek Resources LLC in the amount of $105,806. The promissory bears interest at 16% per annum and matured on June 9, 2017. The amount due was not paid on June 9, 2017, but the holder has not provided the Company a notice of default.

In connection with the May 10, 2017 closing and in consideration of the satisfaction of $13,425,000 of the amount due under the Credit Agreement, as amended, the Company and certain of its subsidiaries transferred to PCR Holdings LLC, an affiliate of the successor lenders under the Credit Agreement, 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 PWCM Investment Company IC LLC (“ PWCM ”), RES Investment Group, LLC (“ RES ”), Round Rock Development Partners, LP (“ Round Rock ”), and Cibolo Holdings, LLC (“ Cibolo Holdings, ” and together with PWCM, RES and Round Rock, “ Successor Lenders ”), the Company’s subsidiaries (except Kansas Holdings, LLC) 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 “ New Credit Agreement ”), and a related Amended and Restated Note (the “ New Note ”), in the amount of $3.3 million as described above.

Our 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.

Recent Funding and Related Transactions

On April 10, 2017, we obtained an unsecured loan in the principal amount of $150,000 from an affiliate of the holder of our issued and outstanding shares of Series B Preferred Stock (the “ lender ”). The loan was converted into 150 shares of Series Convertible Preferred Stock.

On April 27, 2017, the Company entered into an Additional Issuance Agreement with Alpha Capital Anstalt, for the purchase of 300 restricted shares of its newly designated Series C Convertible Preferred Stock in consideration for $300,000, of which $150,000 was payable in cash and $150,000 was payable via a note conversion, with an option to purchase an additional 200 shares of Series C Convertible Preferred Stock for an aggregate purchase price of $200,000. As of June 30, 2017, the Company had issued 300 shares of Series C Convertible Preferred Stock for an aggregate purchase price of $300,000. In addition, during the three months ending June 30, 2017, the Company had received $150,000 from Alpha Capital Anstalt to purchase an additional 150 shares of Series C Convertible Preferred Stock. As of June 30, 2017, the additional 150 shares of Series C Convertible Preferred Stock have not been issued and are reflected as Series C Convertible Preferred Stock Issuable on the balance sheet in the aggregate amount of $150,000. The shares have also not been issued as of the date of this filing.

The Series C Preferred Stock is non-voting (except to the extent required by law and except for certain consent rights relating to amending the certificate of incorporation or bylaws, and the like), ranks senior to the common stock with respect to dividends and with respect to distributions upon a deemed dissolution, liquidation or winding-up of the Company, and ranks junior to the Company’s Series A preferred stock and Series B preferred stock with respect to dividends and with respect to distributions upon a deemed dissolution, liquidation or winding-up of the Company. Upon request of the Holders, the Company can seek stockholder approval to remove the Issuance Limitation described therein and to allow for further adjustments related to anti-dilution protection, only if such stockholder approval is obtained. The Series C Convertible Preferred Stock has a liquidation preference of $1,000 per share, and is convertible at the option of the holder at a conversion price equal to $0.30 per share, or a ratio equal to approximately 3,333 shares of common stock for each one (1) share of Series C Convertible Preferred Stock, subject to customary adjustments. Dividends are payable on the shares of Series C Convertible Preferred Stock only if and to the extent that dividends are payable on the common stock into which the Series C Convertible Preferred Stock is convertible. The Series C Convertible Preferred Stock has no maturity date and can be redeemed by the Company beginning twelve months after the closing of the offering or upon a change of control for the redemption price of $1,000 per share, as adjustable as provided in the designation of the Series C Preferred Stock.

The Series C Preferred Stock includes a beneficial ownership limitation preventing conversion of shares of Series C Preferred Stock into more than 9.99% of the number of shares of common stock outstanding immediately after giving effect to the issuance of shares of common stock upon conversion of the Series C Preferred Stock. In addition, the Company may not convert the Series C Preferred Stock into a number of shares of common stock which, when aggregated with any shares of common stock issued on or after the original issue date and prior to such conversion date in connection with any conversion of Series C Preferred Stock would exceed 1,683,944 shares of common stock (19.99% of the outstanding shares as of the original issue date), subject to adjustment for forward and reverse stock splits, recapitalizations and the like. In the event conversion of the Series C preferred is limited pursuant to these provisions, each holder shall be entitled to pro rata portion of the issuable maximum.

Pursuant to the anti-dilutive provisions of the Securities Purchase Agreement dated as of March 11, 2015, which requires the Company to issue additional shares of common stock to adjust the purchase price paid by purchasers in the Company’s March 2015 offering, in the event any shares are sold (or convertible securities are sold), with a price per share less than the purchase price paid by the March 2015 purchasers subject to the terms of the Securities Purchase Agreement, Alpha Capital Anstalt received 597,461 shares of common stock. In addition, the Series B Convertible Preferred Stock conversion ratio equal to approximately 571 shares of common stock for each one (1) share of Preferred Stock reset to approximately 3,333 shares of common stock for each one (1) share of Series B Convertible Preferred Stock, to be consistent with the terms of the Series C Convertible Preferred Stock, pursuant to the anti-dilution requirements of the Series B Convertible Preferred Stock.

During the three months ending June 30, 2017, Alpha Capital Anstalt converted 390 shares of Series B Convertible Preferred Stock into 1,300,000 shares of common stock.

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. Richard E. Menchaca, a member of the Board of Directors of the Company, is a co-guarantor of bank debt held by Camber Energy, Inc. and Robert Schleizer, our newly appointed Interim Chief Financial Officer is also the Interim Chief Financial Officer of Camber Energy, Inc.

On July 14, 2017, the Company entered into a Secured Promissory Note for $100,000 with Alpha Capital Anstalt, which has a maturity date of November 15, 2017, and accrues interest at a rate of 8% per annum. The amount due under the note is secured by a security interest, subordinate to certain other security interests of the Company, in substantially all of the Company’s assets.

On July 28, 2017, the Company received an advance of $50,000 from Alpha Capital Anstalt.

Summary of product research and development

We do not anticipate performing any significant product research and development under our plan of operations.

Expected purchase or sale of any significant equipment

We anticipate that we will purchase the necessary production and field service equipment required to produce oil during our normal course of operations over the next twelve months.

Significant changes in the number of employees

At June 30, 2017, we had one full-time employee, 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 three and six months ended June 30, 2017, we were not required to record an impairment expense on our evaluated oil and gas properties. For the six months ended June 30, 2016, we incurred a $6,644,596 impairment charge and for the six months ended June 30, 2015 our impairment charge was $27,822,989.

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.