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EX-32.2 - EXHIBIT 32.2 - VICTORY OILFIELD TECH, INC.q32017vyey_ex322.htm
EX-32.1 - EXHIBIT 32.1 - VICTORY OILFIELD TECH, INC.q32017vyey_ex321.htm
EX-31.2 - EXHIBIT 31.2 - VICTORY OILFIELD TECH, INC.q32017vyey_ex312.htm
EX-31.1 - EXHIBIT 31.1 - VICTORY OILFIELD TECH, INC.q32017vyey_ex311.htm


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
Form 10-Q 
(Mark One)
QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2017
TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE EXCHANGE ACT
For the transition period from _______________ to _______________. 
Commission file number 002-76219-NY
VICTORY ENERGY CORPORATION
(Exact Name of Company as Specified in its Charter)
 
Nevada
 
87-0564472
(State or other jurisdiction of incorporation or organization)
 
(I.R.S. Employer Identification No.)
 
 
 
3355 Bee Caves Road Suite 608, Austin, Texas
 
78746
(Address of principal executive offices)
 
 (Zip Code)
(512)-347-7300
(Registrant’s telephone number, including area code)
 
_____________________________________________________________
(Former name, former address and former fiscal year, if changed since last report)
 
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes No
 
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company, or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer”, “smaller reporting company”, and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check one): 
Large accelerated filer
Accelerated filer
Non-accelerated filer
Smaller reporting company
Emerging growth company
 
 
(Do not check if a smaller reporting company)
 
 
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to section 13(a) of the Exchange Act.

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes No
As of November 14, 2017, there were 31,220,326 shares of common stock, par value $0.001, issued and outstanding.





VICTORY ENERGY CORPORATION
QUARTERLY REPORT ON
FORM 10-Q
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2017
 
TABLE OF CONTENTS
 
 
 
Page
 
 
 
Part I – Financial Information
 
 
 
 
Item 1.
Financial Statements
 
 
Condensed Consolidated Balance Sheets as of September 30, 2017 (unaudited) and December 31, 2016
 
Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2017 and 2016 (unaudited)
 
Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2017, and 2016 (unaudited)
 
Notes to the Condensed Consolidated Financial Statements
Item 2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Item 3.
Qualitative and Quantitative Discussions About Market Risk
Item 4.
Controls and Procedures
 
 
 
Part II – Other Information
 
 
 
 
Item 1.
Legal Proceedings
Item 1A.
Risk Factors
Item 2.
Unregistered Sales of Equity Securities and Use of Proceeds
Item 3.
Default Upon Senior Securities
Item 4.
Mine Safety Disclosures
Item 5.
Other Information
Item 6.
Exhibits
 
 
 
Signature

2



Cautionary Notice Regarding Forward Looking Statements
 
We desire to take advantage of the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. This report contains a number of forward-looking statements that reflect management's current views and expectations with respect to business, strategies, future results and events and financial performance. All statements made in this Quarterly Report on Form 10-Q other than statements of historical fact, including statements that address operating performance, events or developments that management expects or anticipates will or may occur in the future, including statements related to revenues, cash flow, profitability, adequacy of funds from operations, statements expressing general optimism about future operating results and non-historical information, are forward looking statements. In particular, the words “believe,” “expect,” “intend,” “anticipate,” “estimate,” “may,” “will,” variations of such words, and similar expressions identify forward-looking statements, but are not the exclusive means of identifying such statements and their absence does not mean that the statement is not forward-looking.

Readers should not place undue reliance on these forward-looking statements, which are based on management’s current expectations and projections about future events, are not guarantees of future performance, are subject to risks, uncertainties and assumptions and apply only as of the date of this report. Our actual results, performance or achievements could differ materially from the results expressed in, or implied by, these forward-looking statements, including, without limitation, the risks outlined under “Item 1A. Risk Factors” included in our Annual Report on Form 10-K for the year ended December 31, 2016, and matters described in this report generally. In light of these risks and uncertainties, there can be no assurance that the forward-looking statements contained in this report will in fact occur.

Potential investors should not place undue reliance on any forward-looking statements. Except as expressly required by the federal securities laws, there is no undertaking to publicly update or revise any forward-looking statements, whether as a result of new information, future events, changed circumstances or any other reason. Potential investors should not make an investment decision based solely on our company’s projections, estimates or expectations.

In particular, our business, including our financial condition and results of operations and our ability to continue as a going concern may be impacted by a number of factors, including, but not limited to, the following:

continued operating losses;
our ability to continue as a going concern;
our dependence on external sources of financing to operate our business and meet our debt service obligations;
difficulties in raising additional capital;
our inability to pay our accounts payable or our expenses as they arise;
our inability to meet the required financial covenants of our lender;
our inability to pay a preferred return to The Navitus Energy Group for capital contributions to Aurora Energy Partners;
challenges in growing our business;
the designation of our common stock as a “penny stock” under the Securities and Exchange Commission, which we refer to as the SEC, regulations;
FINRA requirements that may limit the ability to buy and sell our common stock;
illiquidity and price volatility of our common stock;
the highly speculative nature of an investment in our common stock;
climate change and greenhouse gas regulations;
global economic conditions;
the substantial amount of capital required by our operations;

3




the volatility of oil and natural gas prices;
the high level of risk associated with drilling for and producing oil and natural gas;
assumptions associated with reserve estimates;
the potential that drilling activities will not yield oil or natural gas in commercial quantities;
the potential that exploration, production and acquisitions may not maintain revenue levels in the future;
the potential that our acquisition of additional oil and natural gas assets in the Permian Basin and other future acquisitions may yield revenues or production that differ significantly from our projections;
expenditure of significant resources on potential acquisitions or other projects that we may fail to consummate;
difficulties associated with managing a small and growing enterprise;
strong competition from other oil and natural gas companies;
the unavailability or high cost of drilling rigs and related equipment;
our inability to control properties that we do not operate;
our dependence on third parties for the marketing of our crude oil and natural gas production;
our dependence on key management personnel and technical experts;
our inability to keep pace with technological advancements in our industry;
the potential for write-downs in the carrying values of our oil and natural gas properties;
our compliance with complex laws governing our business;
our failure to comply with environmental laws and regulations;
the demand for oil and natural gas and our ability to transport our production;
the financial condition of the operators of the properties in which we own an interest;
the dilutive effect of additional issuances of our common stock, options or warrants;
any impairments of our oil and natural gas properties;
the results of pending litigation.









4



Glossary of Certain Industry Terms

The definitions set forth below shall apply to the indicated terms as used throughout this Quarterly Report on Form 10-Q.

Bbl. One barrel (of oil or natural gas liquids).

BOE. One barrel of oil equivalent. A BOE is determined using the ratio of six Mcf of natural gas to one Bbl of oil, condensate or natural gas liquids, which approximates the relative energy content of oil, condensate and natural gas liquids as compared to natural gas. Despite holding this ratio constant at six Mcf to one Bbl, prices have historically often been higher or substantially higher for oil than natural gas on an energy equivalent basis, although there have been periods in which they have been lower or substantially lower.

Completion. Installation of permanent equipment for production of oil or gas, or, in the case of a dry well, to reporting to the appropriate authority that the well has been abandoned.

Developed acreage. The number of acres which are allocated or held by producing wells or wells capable of production.

Development well. A well drilled within the proved area of an oil or gas reservoir to the depth of a stratigraphic horizon known to be productive.

Dry hole or dry well. A well found to be incapable of economically producing either oil or gas in sufficient quantities to justify completion as an oil or gas well.

Exploratory well. A well drilled to find a new field or to find a new reservoir in a field previously found to be productive of oil or gas in another reservoir. Generally, an exploratory well is any well that is not a development well, an extension well, a service well, or a stratigraphic test well as those items are defined in Regulation S-X.

Gross acres or gross wells. The total acres or wells, as the case may be, in which a working interest is owned.

Liquids. Describes oil, condensate, and natural gas liquids.
 
MBbls. Thousands of barrels of oil or natural gas liquids.

MBoe. Million barrels of oil equivalent.

Mcf. Thousand cubic feet (of natural gas).

MMcf. Million cubic feet (of natural gas).

Net acres or net wells. The sum of the fractional working interest owned in gross acres or gross wells expressed in whole numbers.

NGL. Natural gas liquids.

Present value or PV10% or SEC PV10%. When used with respect to oil and gas reserves, means the estimated future gross revenue to be generated from the production of net proved reserves, net of estimated production and future development and abandonment costs, using prices and costs under the SEC guideline at the balance sheet date, without giving effect to non-property related expenses such as general and administrative expenses, debt service, accretion, and future income tax expense or to depreciation, depletion, and amortization, discounted using monthly end-of-period discounting at a nominal discount rate of ten percent (10%) per annum.

Productive wells. Producing wells and wells that are capable of production in sufficient quantities to justify completion, including injection wells, salt water disposal wells, service wells, and wells that are shut-in.

Proved developed reserves. Estimated proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods.

Proved reserves. Those quantities of oil and gas, which, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be economically producible—from a given date forward, from known reservoirs, and under existing economic conditions, operating methods, and government regulations—prior to the time at which contracts providing the right to

5



operate expire, unless evidence indicates that renewal is reasonably certain, regardless of whether deterministic or probabilistic methods are used for the estimation.

Proved undeveloped reserves. Estimated proved reserves that are expected to be recovered from new wells on undrilled acreage or from existing wells where a relatively major expenditure is required.

Resource play. Refers to an expansive contiguous geographical area with prospective crude oil and/or natural gas reserves that has the potential to be developed uniformly with repeatable commercial success due to advancements in horizontal drilling and completion technologies.

Undeveloped acreage. Acreage on which wells have not been drilled or completed to a point that would permit the production of commercial quantities of oil or natural gas, regardless of whether such acreage contains estimated proved reserves.

Working Interest or WI. An operating interest which gives the owner the right to drill, produce, and conduct operating activities on the property and a share of production.



6



Part IFinancial Information

Item 1. Financial Statements


7



VICTORY ENERGY CORPORATION AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
 
September 30,
2017
 
December 31,
2016
 
(Unaudited)
 
 
ASSETS
 
 
 
Current Assets
 
 
 
Cash and cash equivalents
$
10,630

 
$
56,456

Accounts receivable
37,755

 
44,379

Accounts receivable - affiliates
207,828

 
137,556

Prepaid expenses
10,096

 
9,951

Total current assets
266,309

 
248,342

Fixed Assets
 
 
 

Furniture and equipment
43,622

 
46,883

Accumulated depreciation
(41,672
)
 
(30,893
)
Total furniture and fixtures, net
1,950

 
15,990

Oil and gas properties, net of impairment (successful efforts method)
2,787,986

 
2,787,986

Accumulated depletion
(2,234,098
)
 
(2,166,643
)
Total oil and gas properties, net
553,888

 
621,343

   Intangible assets
17,630,000

 

Total Assets
$
18,452,147

 
$
885,675

LIABILITIES AND STOCKHOLDERS' EQUITY (DEFICIT)
 
 
 
Current Liabilities
 
 
 

Accounts payable
$
572,295

 
$
420,559

Accrued liabilities
419,069

 
746,491

Accrued liabilities - related parties
65,000

 
1,489,973

Liability for unauthorized preferred stock issued
9,283

 
9,283

Note payable (net of unamortized deferred financing costs)

 
564,263

Note payable (net of debt discount) - affiliate
550,000

 

Asset retirement obligation
63,421

 
76,850

Total current liabilities
1,679,068

 
3,307,419

Other Liabilities
 
 
 

Asset retirement obligations
29,688

 
7,141

Total long term liabilities
29,688

 
7,141

Total Liabilities
1,708,756

 
3,314,560

Stockholders' Equity (Deficit)
 
 
 

Preferred Series B stock, $0.001 par value, 800,000 shares authorized, 800,000 shares and
  0 shares issued and outstanding for September 30, 2017 and December 31, 2016,
respectively
800

 

Preferred Series C stock, $0.001 par value, 810,000 shares authorized, 180,000 shares and
  0 shares issued and outstanding for September 30, 2017 and December 31, 2016,
respectively

180

 

Preferred Series D stock, $0.001 par value, 20,000 shares authorized, 20,000 shares and
  0 shares issued and outstanding for September 30, 2017 and December 31, 2016,
respectively
20

 

Common stock, $0.001 par value, 47,500,000 shares authorized, 31,220,326 shares and 31,220,326 shares issued and outstanding for September 30, 2017 and December 31, 2016, respectively
31,220

 
31,220

  Receivable for stock subscription
(5,000,000
)
 

Additional paid-in capital
60,680,232

 
35,795,479

Accumulated deficit
(47,992,475
)
 
(46,140,750
)

The accompanying notes are an integral part of these condensed consolidated financial statements.
8




Total Victory Energy Corporation stockholders' equity (deficit)
7,719,977

 
(10,314,051
)
Non-controlling interest
9,023,414

 
7,885,166

Total stockholders' equity (deficit)
16,743,391

 
(2,428,885
)
Total Liabilities and Stockholders' Equity (Deficit)
$
18,452,147

 
$
885,675


The accompanying notes are an integral part of these condensed consolidated financial statements.
9




VICTORY ENERGY CORPORATION AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)
 
 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2017
 
2016
 
2017
 
2016
Revenues
 
 
 
 
 
 
 
Oil and gas sales
$
57,764

 
$
73,065

 
$
213,744

 
$
218,243

Gain on settlement and sale of oil and gas properties



 

 
64,824

Total revenues
57,764

 
73,065

 
213,744

 
283,067

Operating Expenses:
 
 
 
 
 
 
 
Lease operating costs
13,145

 
20,585

 
70,885

 
83,712

Exploration and dry hole cost

 

 
2,218

 

Production taxes
3,322

 
4,097

 
11,813

 
11,152

General and administrative
510,636

 
190,675

 
1,628,124

 
1,258,833

Depreciation, depletion, amortization, and accretion
29,916

 
32,729

 
92,216

 
109,016

Total operating expenses
557,019

 
248,086

 
1,805,256

 
1,462,713

Loss from operations
(499,255
)
 
(175,021
)
 
(1,591,512
)
 
(1,179,646
)
Other Income (Expense):
 

 
 

 
 
 
 
Management fee income
869

 
772

 
2,768

 
3,413

Interest expense
(106,742
)
 
(33,300
)
 
(294,733
)
 
(99,613
)
Total other income and expense
(105,873
)
 
(32,528
)
 
(291,965
)
 
(96,200
)
Loss before Tax Benefit
(605,128
)
 
(207,549
)
 
(1,883,477
)
 
(1,275,846
)
Tax benefit

 

 

 

Net loss
(605,128
)
 
$
(207,549
)
 
(1,883,477
)
 
(1,275,846
)
Less: Net loss attributable to non-controlling interest
(5,954
)
 
(12,033
)
 
(31,752
)
 
(95,229
)
Net loss attributable to Victory Energy Corporation
$
(599,174
)
 
$
(195,516
)
 
$
(1,851,725
)
 
$
(1,180,617
)
 
 

 
 

 
 
 
 
Weighted average shares, basic and diluted
31,220,326

 
31,220,326

 
31,220,326

 
31,220,326

Net loss per share, basic and diluted
$
(0.02
)
 
$
(0.01
)
 
$
(0.06
)
 
$
(0.04
)
 

The accompanying notes are an integral part of these condensed consolidated financial statements.
10




VICTORY ENERGY CORPORATION AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOW
(Unaudited) 
 
For the Nine Months Ended September 30,
 
2017
 
2016
CASH FLOWS FROM OPERATING ACTIVITIES
 

 
 

Net loss
$
(1,883,477
)
 
$
(1,275,846
)
Adjustments to reconcile net loss to net cash used in operating activities
 

 
 

Accretion of asset retirement obligations
9,118

 
2,129

Amortization of debt discount
210,000

 

Amortization of deferred financing costs
6,237

 
30,617

Gain on settlement and sale of oil and gas properties

 
(64,824
)
Depletion, depreciation, and amortization
78,234

 
106,887

Stock based compensation
236,221

 
72,071

 
 
 
 
Change in operating assets and liabilities
 

 
 

Accounts receivable
6,624

 
(5,677
)
Accounts receivable - affiliate
(70,272
)
 
(3,413
)
Prepaid expense
(145
)
 
5,238

Accounts payable
151,736

 
(418,151
)
Accrued liabilities - related parties
(255,441
)
 
326,127

Accrued liabilities
(7,422
)
 
(125,515
)
Accrued interest note payable - affiliate
50,000

 

Net cash used in operating activities
(1,468,587
)
 
(1,350,357
)
CASH FLOWS FROM INVESTING ACTIVITIES:
 

 
 

Lease purchases, drilling capital expenditures

 
(18,442
)
Proceeds from sale of assets

 
8,294

         Revisions of furniture and fixtures
3,261

 

Net cash provided by (used in) investing activities
3,261

 
(10,148
)
CASH FLOWS FROM FINANCING ACTIVITIES:
 

 
 

Non-controlling interest contributions
1,170,000

 
1,372,000

Debt financing proceeds - affiliate
820,000

 

Principal payments of debt financing
(570,500
)
 
(8,000
)
Net cash provided by financing activities
1,419,500

 
1,364,000

Net Change in Cash and Cash Equivalents
(45,826
)
 
3,495

Beginning Cash and Cash Equivalents
56,456

 
2,384

Ending Cash and Cash Equivalents
$
10,630

 
$
5,879

 
 
 
 
Supplemental cash flow information:
 
 
 
Cash paid for:
 
 
 
Interest
$
20,469

 
$
33,633

Non-cash investing and financing activities:
 
 
 
Accrued interest and amortization of debt discount
$
274,264

 
$

Accrued capital expenditures
$

 
$
233,323

Revisions to depreciation
$
4,864

 
$

Intangible Assets
$
17,630,000

 
$



The accompanying notes are an integral part of these condensed consolidated financial statements.
11




Victory Energy Corporation and Subsidiary
Notes to the Condensed Consolidated Financial Statements
(Unaudited)

These consolidated financial statements have been prepared by Victory Energy Corporation ("Victory" or the "Company") without audit, pursuant to the rules and regulations of the Securities and Exchange Commission ("SEC"). They reflect all adjustments that are, in the opinion of management, necessary for a fair presentation of the results for the interim periods, on a basis consistent with the annual audited financial statements. All such adjustments are of a normal recurring nature. Certain information, accounting policies, and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States ("GAAP") have been omitted pursuant to such rules and regulations, although the Company believes that the disclosures are adequate to make the information presented not misleading. This Quarterly Report on Form 10-Q should be read along with Victory’s Annual Report on Form 10-K for the fiscal year ended December 31, 2016, which contains a summary of the Company’s significant accounting policies and other disclosures.

Note 1 – Organization and Summary of Significant Accounting Policies
 
Victory, a growth stage, oil and gas exploration and production company, announced on August 22, 2017 that it is transitioning its business into a technology focused oilfield services company, as a result of entering into a transaction agreement, effective August 21, 2017 (the “Transaction Agreement”), sublicense agreement and other related agreements with Armacor Victory Ventures, LLC (“AVV”). In this report, “the Company”, "we" and "our" refers to the consolidated accounts and presentation of Victory and Aurora Energy Partners ("Aurora"), with the equity of non-controlling interests stated separately.

On August 21, 2017, in connection with the Transaction Agreement, the Company entered into a divestiture agreement (the “Divestiture Agreement”) with Navitus Energy Group (“Navitus”), pursuant to which the Company has agreed to divest and transfer its 50% ownership interest in Aurora to Navitus (the “Divestiture”). Closing of the Divestiture Agreement is subject to Shareholder Approval at the shareholders meeting, which is scheduled for November 20, 2017 (the "Shareholders Meeting") and other customary closing conditions, and is expected to occur shortly after approval at the Shareholders Meeting.

The Company's current operations are primarily located onshore in Texas and New Mexico. The Company was organized under the laws of the State of Nevada on January 7, 1982. Our corporate headquarters are located at 3355 Bee Caves Rd. Ste. 608, Austin, Texas.

A summary of significant accounting policies followed in the preparation of the accompanying consolidated financial statements is set forth below.
 
Basis of Presentation and Consolidation:
 
Victory is the managing partner of Aurora, and holds a fifty percent (50%) partnership interest in Aurora. Aurora, a subsidiary of the Company, is consolidated with Victory for financial statement reporting purposes, as the terms of the partnership agreement that govern the operations of Aurora give Victory effective control of the partnership. The consolidated financial statements include the accounts of Victory and the accounts of Aurora. The Company’s management, in considering accounting policies pertaining to consolidation, has reviewed the relevant accounting literature. The Company follows the relevant accounting literature in assessing whether the rights of the non-controlling interests should overcome the presumption of consolidation when a majority voting or controlling interest in its investee “is a matter of judgment that depends on facts and circumstances". In applying the circumstances and contractual provisions of the partnership agreement, management determined that the non-controlling rights do not, individually or in the aggregate, provide for the non-controlling interest to “effectively participate in significant decisions that would be expected to be made in the ordinary course of business.” The rights of the non-controlling interest are protective in nature. All intercompany balances have been eliminated in consolidation. Certain reclassifications of prior year balances have been made to confirm such amounts to current year classifications. The reclassifications have no prior impact on net income. As discussed above, the Company entered into a Divestiture Agreement with Navitus. Upon the closing of the Divestiture Agreement, Aurora will no longer be consolidated with Victory for financial statement reporting purposes.
  
Non-controlling Interests:
 
The Navitus Energy Group ("Navitus"), a Texas general partnership, is a partner with Victory in Aurora. The two partners each own a fifty percent (50%) interest in Aurora. Victory is the Managing partner and has contractual authority to manage the business affairs of Aurora. Navitus currently has four partners. They are James Capital Consulting, LLC ("JCC"), James Capital Energy, LLC ("JCE"), Rodinia Partners, LLC and Navitus Partners, LLC. Although this partnership has been in place since January 2008, its members and other elements have changed since that time. 

12



 
The non-controlling interest in Aurora is held by Navitus. As of September 30, 2017, $9,023,414 was recorded as the equity of the non-controlling interest in our consolidated balance sheets representing a third-party investment in Aurora, with net loss attributable to non-controlling interest of $5,954 and $12,033 for the three months ended September 30, 2017 and 2016, respectively, and $31,752 and $95,229 for the nine months ended September 30, 2017 and 2016, respectively. As of December 31, 2016, $7,885,166 was recorded as the equity of the non-controlling interest in our consolidated balance sheets representing a third-party investment in Aurora. As discussed above, the Company entered into a Divestiture Agreement with Navitus. Upon the closing of the Divestiture Agreement, Aurora will no longer be consolidated with Victory for financial statement reporting purposes.

Use of Estimates:

The preparation of our consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Estimates are used primarily when accounting for depreciation, depletion, and amortization (“DD&A”) expense, property costs, estimated future net cash flows from proved reserves, assumptions related to abandonments and impairments of oil and natural gas properties, taxes, accruals of capitalized costs, operating costs and production revenue, general and administrative costs and interest, purchase price allocation on properties acquired, various common stock, warrants and option transactions, and loss contingencies.

Oil and Natural Gas Properties:

We account for investments in oil and natural gas properties using the successful efforts method of accounting. Under this method of accounting, only successful exploration drilling costs that directly result in the discovery of proved reserves are capitalized. Unsuccessful exploration drilling costs that do not result in an asset with future economic benefit are expensed. All development costs are capitalized because the purpose of development activities is considered to be building a producing system of wells, and related equipment facilities, rather than searching for oil and natural gas. Items charged to expense generally include geological and geophysical costs. Capitalized costs for producing wells and leasehold costs of proved properties are amortized on a unit-of-production basis over the remaining life of proved developed and total proved reserves, respectively.

We review our proved oil and gas properties for impairment whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. We estimate the expected undiscounted future cash flows of our oil and gas properties and compare such undiscounted future cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, we will adjust the carrying amount of the oil and gas properties to fair value. The factors used to determine fair value are subject to our judgment and expertise and include, but are not limited to, recent sales prices of comparable properties, the present value of future cash flows, net estimated operating and development costs using estimates of proved reserves, future commodity pricing, future production estimates, anticipated capital expenditures, and various discount rates commensurate with the risk and current market conditions associated with realizing the expected cash flows projected. Because of the uncertainty inherent in these factors, we cannot predict when or if future impairment charges for proved properties will be recorded.

The assessment of unproved properties to determine any possible impairment requires significant judgment. We assess our unproved properties to determine any possible impairment on a property-by-property basis based on remaining lease terms, drilling results or future plans to develop acreage. Due to the uncertainty inherent in these factors, we cannot predict the amount of impairment charges that may be recorded in the future.

The Company recorded no impairment expense for the three and nine months ended September 30, 2017 and 2016, respectively based on the analysis above.

Asset Retirement Obligations:

The Company records the estimate of the fair value of liabilities related to future asset retirement obligations (“ARO”) in the period the obligation is incurred. Asset retirement obligations relate to the removal of facilities and tangible equipment at the end of an oil and natural gas property’s useful life. The application of this rule requires the use of management’s estimates with respect to future abandonment costs, inflation, market risk premiums, useful life and cost of capital and required government regulations. GAAP requires that the estimate of our ARO does not give consideration to the value the related assets could have to other parties.

Other Property and Equipment:


13



Our office equipment in Austin, Texas is being depreciated on the straight-line method over the estimated useful life of three to seven years. The Company recorded depreciation expense of $1,461 and $10,779 for the three and nine months ended September 30, 2017.

Intangible Assets:

Our intangible assets are comprised of contract-based and marketing-related intangible assets. Our contract-based intangible assets include a sublicense agreement and a trademark license. The contract-based intangible assets have useful lives of 11.1 years to 15 years. As of September 30, 2017 the Company has not begun to use the economic benefits of the sublicense agreement and the trademark license and, accordingly, they were not amortized. We will begin to amortize the contract-based intangible assets using the straight-line amortization method over their respective useful lives once we have begun to use their economic benefits. Our marketing related intangible assets include three non-compete agreements all of which have useful lives of 15 years. As of September 30, 2017 the Company has not begun to use the economic benefits of the non-compete agreements and, accordingly, they were not amortized. We will begin to amortize the marketing-related intangible assets using the straight-line amortization method over their respective useful lives once we have begun to use their economic benefits. The remaining useful lives of intangible assets will be evaluated each reporting period. Intangible assets will be tested for impairment at least annually and upon a triggering event. The following table shows intangible assets and related accumulated amortization as of September 30, 2017 and December 31, 2016:
 
 
September 30,
 
December 31,
 
 
2017
 
2016
Sublicense agreement
 
$
11,330,000

 
$

Trademark license
 
6,030,000

 

Non-compete agreements
 
270,000

 

Accumulated amortization
 

 

Intangible assets, net

 
$
17,630,000

 
$


Cash and Cash Equivalents:

The Company considers all liquid investments with original maturities of three months or less from the date of purchase that are readily convertible into cash to be cash equivalents. The Company had no cash equivalents at September 30, 2017 and December 31, 2016.

Accounts Receivable:

Our accounts receivable are primarily from purchasers of natural gas and oil and exploration and production companies which own an interest in properties we operate.

Fair Value:

At September 30, 2017 and December 31, 2016, the carrying value of the Company's financial instruments such as prepaid expenses and payables approximated their fair values based on the short-term maturities of these instruments. The carrying value of other liabilities approximated their fair values because the underlying interest rates approximated market rates at the balance sheet dates. Management believes that due to the Company's current credit worthiness, the fair value of debt could be less than the book value; however, due to current market conditions and available information, the fair value of such debt is not readily determinable. Financial Accounting Standard Board ("FASB") Accounting Standards Codification ("ASC") Topic 820, Fair Value Measurements and Disclosures, established a hierarchical disclosure framework associated with the level of pricing observability utilized in measuring fair value. This framework defined three levels of inputs to the fair value measurement process and requires that each fair value measurement be assigned to a level corresponding to the lowest level input that is significant to the fair value measurement in its entirety. The three broad levels of inputs defined by FASB ASC Topic 820 hierarchy are as follows:

Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date;

Leve1 2 - inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly or indirectly. If the asset or liability has a specified (contractual) term, a Leve1 2 input must be observable for substantially the full term of the asset or liability; and


14



Leve1 3 - unobservable inputs for the asset or liability. These unobservable inputs reflect the entity's own assumptions about the assumptions that market participants would use in pricing the asset or liability and are developed based on the best information available in the circumstances (which might include the reporting entity's own data).

The initial measurement of ARO is calculated using discounted cash flow techniques and based on internal estimates of future ARO costs associated with proved oil and gas properties. Inputs used in the calculation of ARO include plugging costs and reserve lives, which are considered Level 3 inputs. A reconciliation of Victory’s ARO is presented in Note 4.

Unamortized Discount:

Unamortized discount consists of value attributed to free standing equity instruments issued to the holders of affiliate note payable (see Note 6) and are amortized over the life of the related loans using a method consistent with the interest method. Amortization of debt discount totaled $210,000 for the nine months ended September 30, 2017 and is included in interest expense in the condensed consolidated statements of operations. The following table shows the discount and related accumulated amortization as of September 30, 2017 and December 31, 2016:

 
 
September 30,
 
December 31,
 
 
2017
 
2016
Original issuance discount
 
$
210,000

 
$

 
 
 
 
 
Accumulated amortization
 
(210,000
)
 

 
 
 
 
 
Unamortized discount, net
 
$

 
$


Revenue Recognition:

The Company uses the sales method of accounting for oil and natural gas revenues. Under this method, revenues are recognized based on actual volumes of gas and oil sold to purchasers. The volumes sold may differ from the volumes to which the Company is entitled based on our interests in the properties. Differences between volumes sold and entitled volumes create oil and natural gas imbalances which are generally reflected as adjustments to reported proved oil and natural gas reserves and future cash flows in their supplemental oil and natural gas disclosures. If their excess takes of natural gas or oil exceed their estimated remaining proved reserves for a property, a natural gas or oil imbalance liability is recorded in the Consolidated Balance Sheets.

Concentrations:
 
There is a ready market for the sale of crude oil and natural gas. During 2017 and 2016, our gas field and our producing wells sold their respective gas and oil production to one purchaser for each field or well. However, because alternate purchasers of oil and natural gas are readily available at similar prices, we believe that the loss of any of our purchasers would not have a material adverse effect on our financial results. A majority of the Company’s production and reserves are from the Eagle Ford property in South Texas and the Permian Basin of West Texas.

Earnings (Losses) per Share:

Basic earnings per share (“EPS”) is computed by dividing net income (loss) attributable to controlling interests by the weighted-average number of shares of common stock outstanding during the period. Diluted EPS takes into account the dilutive effect of potential common stock that could be issued by the Company in conjunction with stock awards that have been granted to directors and employees. In accordance with FASB ASC 260, Earnings per Share, awards of unvested shares shall be considered outstanding as of the respective grant dates for purposes of computing diluted EPS even though their exercise is contingent upon vesting. Given the historical and projected future losses of the Company, all potentially dilutive common stock equivalents are considered anti-dilutive.

Income Taxes:

The Company accounts for income taxes in accordance with FASB ASC 740, Income Taxes, which requires an asset and liability approach for financial accounting and reporting of income taxes. Deferred income taxes reflect the impact of temporary differences between the amount of assets and liabilities for financial reporting purposes and such amounts as measured by tax laws and

15



regulations. Deferred tax assets include tax loss and credit carry forwards and are reduced by a valuation allowance if, based on available evidence, it is more likely than not that some portion or all of the deferred tax assets will not be realized.

The realization of future tax benefits is dependent on our ability to generate taxable income within the carry forward period. Given the Company’s history of net operating losses, management has determined that it is likely that the Company will not be able to realize the tax benefit of the carry forwards. ASC 740 requires that a valuation allowance be established when it is more likely than not that all or a portion of deferred tax assets will not be realized.
 
Accordingly, the Company has a full valuation allowance against its net deferred tax assets at September 30, 2017 and December 31, 2016. Upon the attainment of taxable income by the Company, management will assess the likelihood of realizing the deferred tax benefit associated with the use of the net operating loss carry forwards and will recognize a deferred tax asset at that time.

Stock-Based Compensation:
 
The Company applies FASB ASC 718, Compensation-Stock Compensation, to account for the issuance of options and warrants to employees, key partners, directors, officers and Navitus investors. The standard requires all share-based payments, including employee stock options, warrants and restricted stock, be measured at the fair value of the award and expensed over the requisite service period (generally the vesting period). The fair value of options and warrants granted to employees, directors and officers is estimated at the date of grant using the Black-Scholes option pricing model by using the historical volatility of the Company’s stock price. The calculation also takes into account the common stock fair market value at the grant date, the exercise price, the expected term of the common stock option or warrant, the dividend yield and the risk-free interest rate.
 
The Company from time to time may issue stock options, warrants and restricted stock to acquire goods or services from third-parties. Restricted stock, options or warrants issued to third parties are recorded on the basis of their fair value, which is measured as of the date issued. The options or warrants are valued using the Black-Scholes option pricing model on the basis of the market price of the underlying equity instrument on the “valuation date,” which for options and warrants related to contracts that have substantial disincentives to non-performance, is the date of the contract, and for all other contracts is the vesting date. Expense related to the options and warrants is recognized on a straight-line basis over the shorter of the period over which services are to be received or the vesting period and is included in general and administrative expenses in the accompanying consolidated statements of operations.
 
The Company recognized stock-based compensation expense from stock awards, warrants, and stock options granted to directors, officers, employees and third parties of $101,415 and $14,662 for the three months ended September 30, 2017 and 2016, respectively and $236,221 and $72,071 for the nine months ended September 30, 2017 and 2016, respectively.

Recently Adopted Accounting Standards:

In January 2017, FASB issued Accounting Standards Update (“ASU”) 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business, which changes the definition of a business to assist entities with evaluating when a set of transferred assets and activities is deemed to be a business. Determining whether a transferred set constitutes a business is important because the accounting for a business combination differs from that of an asset acquisition. The definition of a business also affects the accounting for dispositions. Under ASU 2017-01, when substantially all of the fair value of assets acquired is concentrated in a single asset, or a group of similar assets, the assets acquired would not represent a business and business combination accounting would not be required. ASU 2017-01 may result in more transactions being accounted for as asset acquisitions rather than business combinations. ASU 2017-01 is effective for interim and annual periods beginning after December 15, 2017 and shall be applied prospectively. Early adoption is permitted. The Company adopted ASU 2017-01 on January 1, 2017 and will apply the new guidance to applicable transactions going forward.

In March 2016, FASB issued guidance regarding the simplification of employee share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. We adopted this guidance in the second quarter of 2016 as permitted by the guidance. Adoption of this guidance did not impact our financial statements, except for the simplification in accounting for income taxes using a modified retrospective approach. Upon adoption, we recorded a related deferred tax asset for previously unrecognized excess tax benefits of $37 million. As we consider it more likely than not that the deferred tax asset will not be realized, we recorded a full valuation allowance of $37 million, resulting in no net effect on our consolidated statement of operations. We elected to continue our current policy of estimating forfeitures.

In April 2015, FASB issued ASU 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. Entities that have historically presented debt issuance costs as an asset, related to a recognized debt liability,

16



will be required to present those costs as a direct deduction from the carrying amount of that debt liability. ASU 2015-03 does not change the recognition, measurement, or subsequent measurement guidance for debt issuance costs. In August 2015, FASB issued ASU 2015-15, Interest—Imputation of Interest (Subtopic 835-30), which addresses the presentation or subsequent measurement of debt issuance costs related to line-of-credit arrangements, given the absence of authoritative guidance within ASU 2015-03 for debt issuance costs related to line-of-credit arrangements. The amendments are effective for interim and annual reporting periods beginning after December 15, 2015. Therefore, the Company adopted ASU 2015-03 beginning January 1, 2016. Changes to the balance sheet have been applied on a retrospective basis. This resulted in the reclassification of debt issuance costs of $6,237 and $40,823 associated with our Credit Agreement from Other Assets to Current Note Payable in the Consolidated Balance Sheet as of the nine months ended September 30, 2017 and the year ended December 31, 2016.

In February 2015, FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidated Analysis. ASU 2015-02 amended the consolidation guidance by modifying the evaluation criteria for whether limited partnerships and similar legal entities are variable interest entities, eliminating the presumption that a general partner should consolidate a limited partnership, and affecting the consolidated analysis of reporting entities that are involved with variable interest entities. The adoption of ASU 2015-02, effective January 1, 2016, did not have a material impact on our consolidated balance sheets, statements of operations or statements of cash flows.

Recently Issued Accounting Standards:

In February 2016, the FASB issued guidance regarding the accounting for leases. The guidance requires recognition of most leases on the balance sheet. The guidance requires lessees and lessors to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The guidance is effective for interim and annual periods beginning after December 15, 2018. We are currently evaluating the impact of this guidance on our consolidated financial statements.

In January 2016, the FASB issued guidance regarding several broad topics related to the recognition and measurement of financial assets and liabilities. The guidance is effective for interim and annual periods beginning after December 15, 2017. We do not expect this guidance to have a material impact on our consolidated financial statements.

In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. In April 2016, May 2016 and December 2016, FASB issued additional guidance, addressed implementation issues and provided technical corrections. The guidance may be applied retrospectively or using a modified retrospective approach to adjust retained earnings (deficit). The guidance is effective for interim and annual periods beginning after December 15, 2017. We are currently evaluating the impact of this guidance on our consolidated financial statements.

Going Concern:
 
The accompanying consolidated financial statements have been prepared assuming the Company will continue as a going concern, which contemplates the realization of assets and satisfaction of liabilities in the normal course of business. As presented in the consolidated financial statements, the Company has incurred a net loss of $599,174 and $195,516 for the three months ended September 30, 2017 and 2016, respectively, and net losses of $1,851,725 and $1,180,617 for the nine months ended September 30, 2017 and 2016, respectively.

The cash proceeds from new contributions to the Aurora partnership by Navitus, and loans from affiliates have allowed the Company to continue operations. Management anticipates that operating losses will continue in the near term until the Company begins to operate as a technology focused oilfield services company. The Company has invested $0 and $18,442, respectively, in leases, and drilling and completion costs, for the nine months ended September 30, 2017 and 2016, respectively.
On August 21, 2017 the Company entered into a loan agreement (the “Loan Agreement”) with Visionary Private Equity Group I, LP, a Missouri limited partnership (“VPEG”) pursuant to which VPEG loaned $500,000 to the Company. This loan provided short-term financing required for operating and transaction expenses.

On August 21, 2017, the Company entered into a Transaction Agreement with Armacor, pursuant to which Armacor (i) granted to the Company a worldwide, perpetual, royalty free, fully paid up and exclusive sublicense (the “License”) to all of Armacor’s owned and licensed intellectual property for use in the Oilfield Services Business (as defined in the Transaction Agreement), and (ii) agreed to contribute to the Company $5,000,000 (the “Cash Contribution”), in exchange for which the Company issued 800,000 shares (the “Armacor Shares”) of its newly designated Series B Convertible Preferred Stock. The Cash contribution is expected upon Shareholder Approval and will provide financing for the development and execution of the sales and distribution business growth plan.


17



The accompanying consolidated financial statements are prepared as if the Company will continue as a going concern. The consolidated financial statements do not contain adjustments, including adjustments to recorded assets and liabilities, which might be necessary if the Company were unable to continue as a going concern.

Note 2 - Acquisitions and Dispositions

During February 2015, Victory entered into a letter of intent ("LOI") and subsequently into (a) the Pre-Merger Collaboration Agreement (the “Collaboration Agreement”) with Lucas Energy Inc. (“Lucas”), Navitus and AEP Assets, LLC ("AEP"), a wholly-owned subsidiary of Aurora; and (b) the Pre-Merger Loan and Funding Agreement (the “Loan Agreement”) with Lucas. During March 2015 the parties entered into Amendment No. 1 to the Pre-Merger Collaboration which amendments affected thereby are included in the discussion of the Collaboration Agreement below. Payments of $195,928 and $317,027 were made by Aurora, on behalf of Victory, to Earthstone Energy/Oak Valley Resources and Penn Virginia, respectively, for costs related to the two Earthstone Energy/ Oak Valley Resources and the five Penn Virginia operated Eagle Ford wells, respectively.

The initial draw, and additional amounts borrowed by Lucas under the Loan Agreement were evidenced by a Secured Subordinated Delayed Draw Term Note issued by Lucas in favor of Victory, which was in an initial amount of $250,000 (the “Draw Note”). Borrowings evidenced by the Draw Note accrued interest at one-half of one percent (0.5%) per annum, with accrued interest payable in one lump sum on maturity. The maturity date of the Draw Note was February 26, 2015. A total of $600,000 was paid to Lucas under the Draw Note.

Subsequent to March 31, 2015, the Company terminated the LOI and notified Lucas pursuant to the Loan Agreement, that it would not extend any further credit to Lucas under the Loan Agreement. There were $0 associated costs incurred during the nine-month periods ended September 30, 2017 and 2016.

Further, the Company entered into: (1) a Settlement Agreement and Mutual Release (the “Lucas Settlement Agreement”) with Lucas; (2) a Settlement Agreement and Mutual Release (the “Rogers Settlement Agreement”) with Louise H. Rogers, (“Rogers”), and; (3) a Compromise Settlement Agreement and Mutual General Release, effective as of September 25, 2015 (the “Earthstone Settlement Agreement”, and, together with the Lucas Settlement Agreement and the Rogers Settlement Agreement, the “Settlement Agreements”) with Earthstone Operating, LLC, Earthstone Energy, Inc., Oak Valley Resources, LLC, Oak Valley Operating LLC and Sabine River Energy, LLC (collectively, “Earthstone”), Lucas, AEP, and Aurora.

Lucas Settlement Agreement

The Company and Lucas agreed to terminate any and all obligations between the parties arising under the LOI and the Collaboration Agreement. The Company and Lucas further agreed that the Company would retain ownership and control over five Penn Virginia well-bores previously assigned by Lucas to the Company (the “Penn Virginia Well-Bores”), as well as the obligations to pay the expenses associated with such Penn Virginia Well-Bores effective after August 1, 2014. Under the terms of the Lucas Settlement Agreement, Lucas agreed to assign to the Company all of Lucas’ rights in a certain oil and gas property located in the same field as the Penn Virginia Well-Bores (the “Additional Penn Virginia Property”), including the rights to all revenues from all wells on some properties.

Rogers Settlement and Amended Rogers Settlement Agreements

The Company and Rogers agreed, among other things: (i) to terminate the contingent promissory note in the principal amount of $250,000 payable to Rogers that was issued by Victory in connection with the entry by Lucas and the Company into the Collaboration Agreement; (ii) that the Company would pay Rogers, on or before July 15, 2015, $258,125; and (iii) that Rogers’ legal counsel will hold the assignment of the Additional Penn Virginia Property and the Settlement Shares in escrow until such time as the payment of $258,125 is made by the Company to the Rogers. Failure of the Company to make the payment of $258,125 on or before July 15, 2015, would result in the Company being in default under the Rogers Settlement Agreement and default interest on the amount due would begin to accrue at a per diem rate of $129.0625. Additionally, the Company acknowledged in the Amendment its obligation to pay Rogers’ attorney’s fees in the amount of $26,616. The Company has not made any payments to Rogers pursuant to the Rogers Settlement Agreement and as a result the additional Penn Virginia Property

18



was returned to Lucas in September 2015. The full amount due under the Roger’s obligation including accrued interest at September 30, 2017 totals $362,408 and is included in accrued liabilities on the consolidated balance sheet.

Divestiture Agreement

On August 21, 2017, in connection with the Transaction Agreement, the Company entered into a Divestiture Agreement with Navitus, pursuant to which the Company has agreed to divest and transfer its 50% ownership interest in Aurora to Navitus, which currently owns the remaining 50% interest, in consideration for a release from Navitus of all of the Company’s obligations under the second amended partnership agreement, dated October 1, 2011, between Victory and Navitus (the “Partnership Agreement”), including, without limitation, obligations to return to Navitus investors their accumulated deferred capital, deferred interest and related allocations of equity. The Company has also agreed to pay off or otherwise satisfy all indebtedness and other material liabilities of Aurora at or prior to closing of the Divestiture Agreement.

Closing of the Divestiture Agreement is subject to Shareholder Approval at the Shareholders Meeting and other customary closing conditions, including, without limitation, the receipt of all authorizations, consents and approvals of all governmental authorities or agencies; the receipt of any required consents of any third parties; execution of an amendment and restatement of the Partnership Agreement; and execution of a mutual release by the parties. Closing is expected to occur shortly after approval at the Shareholders Meeting.

The Divestiture Agreement may be terminated (i) by mutual written consent, (ii) by either party if any governmental entity has issued an order or taken any other action permanently enjoining, restraining or otherwise prohibiting the transactions contemplated by Divestiture Agreement, (iii) by either party if the other party has breached is representations and warrants or any covenant or other agreement to be performed by it in a manner such that the closing conditions would not be satisfied; (iv) by Navitus if (a) its conditions set forth in the Divestiture Agreement have been satisfied and the Company fails to consummate the Divestiture on the date the closing should have occurred pursuant to the Divestiture Agreement and (b) Navitus has irrevocably confirmed in writing that all the Company’s conditions set forth in the Divestiture Agreement have been satisfied or that it is willing to waive all unsatisfied conditions and it stands ready, willing and able to consummate the closing on such date; or (v) by the Company if (a) its conditions set forth in the Divestiture Agreement have been satisfied and Navitus fails to consummate the Divestiture on the date the closing should have occurred pursuant to the Divestiture Agreement and (b) the Company has irrevocably confirmed in writing that all Navitus’ conditions set forth in the Divestiture Agreement have been satisfied or that it is willing to waive all unsatisfied conditions and it stands ready, willing and able to consummate the closing on such date.

The foregoing summary of the terms and conditions of the Divestiture Agreement does not purport to be complete and is qualified in its entirety by reference to the full text of that agreement filed as an exhibit to this report.

Note 3 – Oil and natural gas properties, net of accumulated impairment (under successful efforts accounting)

Oil and natural gas properties are comprised of the following: 
 
September 30,
2017
 
December 31, 2016
Proved property
$
9,695,367

 
$
9,695,367

Unproved property
$
1,375,940

 
$
1,375,940

Total oil and natural gas properties, at cost
$
11,071,307

 
$
11,071,307

Less: accumulated impairment
$
(8,283,321
)
 
$
(8,283,321
)
Oil and natural gas properties, net of impairment
$
2,787,986

 
$
2,787,986

Less: accumulated depletion
(2,234,098
)
 
(2,166,643
)
Oil and natural gas properties, net
$
553,888

 
$
621,343

 
Depletion and accretion expense for the three months ended September 30, 2017 and 2016 was $28,455 and $31,114, respectively, and $76,573 and $104,168 for the nine months ended September 30, 2017 and 2016, respectively. During the three and nine months ended September 30, 2017 and 2016, the Company recorded no impairment losses. 

Note 4 – Asset Retirement Obligations

The following table is a reconciliation of the ARO liability as of and for the nine months ended September 30, 2017 and the twelve months ended December 31, 2016.
 
 
September 30,
2017
 
December 31, 2016
Asset retirement obligation at beginning of period
$
83,991

 
$
109,171

Liabilities incurred on properties acquired and developed

 

Revisions to previous estimates
7,486

 

Liabilities on properties sold or settled

 
(27,850
)
Accretion expense
1,632

 
2,670

Asset retirement obligation at end of period
$
93,109

 
$
83,991


Note 5 – Revolving Credit Agreement
 
On February 20, 2014, Aurora, as borrower, entered into a credit agreement (the "Credit Agreement") with Texas Capital Bank (“the Lender”). Guarantors on the Credit Agreement are Victory and Navitus, the two partners of Aurora. Pursuant to the Credit Agreement, the Lender agreed to extend credit to Aurora in the form of: (a) one or more revolving credit loans (each such loan, a “Loan”); and (b) the issuance of standby letters of credit, of up to an aggregate principal amount at any one time not to exceed the lesser of: (i) $25,000,000; or (ii) the borrowing base in effect from time to time (the “Commitment”). The initial borrowing base on February 20, 2014 was set at $1,450,000. The borrowing base is determined by the Lender, in its sole discretion, based on customary lending practices, review of the oil and natural gas properties included in the borrowing base, financial review of Aurora, the Company and Navitus and such other factors as may be deemed relevant by the Lender. The borrowing base is re-determined: (i) on or about September 30 of each year based on the previous December 31 reserve report prepared by an independent reserve engineer; and (ii) on or about August 31 of each year based on the previous September 30 reserve report prepared by Aurora’s internal reserve engineers or an independent reserve engineer and certified by an officer of Aurora. The Credit Agreement will mature on February 20, 2017. Amounts borrowed under the Credit Agreement will bear interest at rates equal to the lesser of: (i) the maximum rate of interest which may be charged or received by the Lender in accordance with applicable Texas law; and (ii) the interest rate per annum publicly announced from time to time by the Lender as the prime rate in effect at its principal office plus the applicable margin. The applicable margin is: (i) with respect to Loans, one percent (1.00%) per annum; (ii) with respect to letter of credit fees, two percent (2.00%) per annum; and (iii) with respect to commitment fees, one-half of one percent (0.50%) per annum. Loans made under the Credit Agreement are secured by: (i) a first priority lien in the oil and gas properties of Aurora, the Company and Navitus; and (ii) a first priority security interest in substantially all of the assets of Aurora and its subsidiaries, if any, as well as in all (100%) of the partnership interests in Aurora held by the Company and Navitus. Loans made under the Credit Agreement to Aurora are fully guaranteed by the Company and Navitus.
 
The Credit Agreement contains various affirmative and negative covenants. These covenants, among other things, limit additional indebtedness, additional liens and transactions with affiliates. Among the covenants contained in the Credit Agreement are financial covenants that Aurora will maintain a minimum earnings before interest, taxes, depreciation, depletion, amortization, and exploration expenses ("EBITDAX") to Cash Interest Ratio of 3.5 to 1.0 and a minimum Current Ratio of not less than 1.0 to 1.0. The Current Ratio is defined under the covenants to include, as a current asset, the revolving credit availability.

On April 13, 2015, the Company received the annual Borrowing Base Adjustment called for under the terms of the Credit Agreement, which called for a decrease in the borrowing base of $300,000 payable by May 13, 2015, and an increase in the monthly reduction amount to $10,000 commencing as of June 1, 2015. Additionally, the Lender notified Aurora that, based on the Lender’s redetermination of Aurora’s borrowing base, the monthly reduction amount under the Credit Agreement will be increased, commencing on June 1, 2015, from $0 to $10,000. Pursuant to this increase in the monthly reduction amount, Aurora’s borrowing base will be automatically reduced by $10,000 on the first day of each calendar month beginning in June 2015 until the Lender’s next periodic borrowing base redetermination. The Company made one payment in the amount of $10,000 in June 2015.

On May 13, 2015, Aurora informed the Lender it would not make the required $300,000 payment but was submitting the newly acquired five Eagle Ford wells as additional collateral to be considered and its willingness to execute mortgages regarding the properties to meet the Deficiency.

On August 21, 2015, the Company executed a Forbearance Agreement whereby the Lender would forbear all existing events of default which includes all payments under the previously mentioned Borrowing Base Deficiency payments not yet paid under the April 13, 2015 Redetermination Date notification, as well as the late interest payments for June, July and August 2015, violations of Aurora financial covenants for the three months ended March 31, 2015, and June 30, 2015, and default notice for the late filing of March 31, 2015 financial reports. On August 26, 2015, the Company paid the Lender $76,081 to cover a portion of the deficiency

19



payment, as well as a Forbearance document fee and Lender's legal expenses, as required by the Forbearance Agreement, and the aforementioned Forbearance Agreement went into effect for the $260,000 remaining borrowing base deficiency payment. On August 31, 2015, the Forbearance Agreement terminated pursuant to its terms. The Company did not make the above payment and has been in continuous contact with its lender regarding its plan of payment of the $260,000 as well as the remaining credit facility balance. The Company made a $50,000 principle payment to the Lender on October 14, 2015 as part of that plan.

On December 5, 2016, the Company entered into a new Forbearance Agreement to the Credit Agreement. Pursuant to the Forbearance Agreement, the Lender agreed to forbear from exercising any of its rights and remedies under the Credit Agreement until February 20, 2017 with respect to the historical events of default.

The Forbearance Period was amended and extended on March 2, 2017 and will end on the first to occur of the following: (i) the expiration of the amended Forbearance Period on August 20, 2017; (ii) a breach by Aurora or any Guarantor of any of the conditions, covenants, representations and/or warranties set forth in the Forbearance Agreement; (iii) the occurrence of any new event of default under the Credit Agreement; (iv) the occurrence or threat of the occurrence of any enforcement action against Aurora or any Guarantor by any of their creditors which, in Lender’s reasonable judgment, would materially interfere with the operation of Aurora’s or the Guarantor’s business or the Lender’s ability to collect on the obligations due under the Credit Agreement; (v) the institution of any bankruptcy proceeding relating to Aurora or any Guarantor; or (vi) the initiation by Aurora or any Guarantor of any judicial, administrative or arbitration proceedings against the Lender. The Lender’s agreement to forbear from exercising its rights and remedies as a result of the Existing Events of Default is subject to and conditioned upon the following: (i) the payment by Aurora to the Lender of at least $20,000 on or before the last business day of each calendar week occurring hereafter; and (ii) the delivery by Aurora of such other documents, instruments and certificates as reasonably requested by Lender. The foregoing description of the Forbearance Agreement is a summary only and is qualified in its entirety by reference to the complete text of the Forbearance Agreement. Since the execution of the extended Forbearance Agreement, the Company has paid the Lender $570,500. The balance owed on the Credit Agreement was $0 and $672,000 as of September 30, 2017 and December 31, 2016, respectively.
Amortization of debt financing costs on this debt was $6,237 and $30,617 for the nine months ended September 30, 2017 and 2016, respectively. Interest expense was $20,415 and $33,633 for the nine months ended September 30, 2017, and 2016, respectively. 

Note 6 – Related Party Transactions

As discussed in Note 2 - Acquisitions and Dispositions, on August 21, 2017, in connection with the Transaction Agreement, the Company entered into a Divestiture Agreement with Navitus pursuant to which the Company has agreed to divest and transfer its 50% ownership interest in Aurora to Navitus (the “Divestiture”), which currently owns the remaining 50% interest, in consideration for a release from Navitus of all of the Company’s obligations under the second amended partnership agreement, dated October 1, 2011, between Victory and Navitus (the “Partnership Agreement”)

On August 21, 2017, in connection with the Transaction Agreement, the Company entered into a settlement agreement and mutual release (the “VPEG Settlement Agreement”) with Visionary Private Equity Group I, LP ("VPEG"), pursuant to which all obligations of the Company to VPEG to repay indebtedness for borrowed money, other than the VPEG Note (described below), which totaled $873,409.64, including all accrued, but unpaid, interest thereon, was converted into 110,000.472149068 shares (the “VPEG Shares”) of the Company’s newly designated Series C Preferred Stock. Some of the obligations of the Company to VPEG arose pursuant to a securities purchase agreement, dated February 1, 2017, between the Company and VPEG, pursuant to which VPEG purchased a unit comprised of (i) a twelve percent (12%) unsecured six-month promissory note in the principal amount of $320,000 and (ii) a common stock purchase warrant to purchase 5,203,252 shares of the Company’s Common Stock at an exercise price of $0.0923 per share. Pursuant to the VPEG Settlement Agreement, the twelve percent (12%) unsecured six-month promissory note was repaid in full and terminated, but VPEG retained the common stock purchase warrant.

On August 21, 2017, in connection with the Transaction Agreement, the Company entered into a settlement agreement and mutual release (the “Navitus Settlement Agreement”) with Ron Zamber and Greg Johnson, affiliates of Navitus, pursuant to which all obligations of the Company to Ron Zamber and Greg Johnson to repay indebtedness for borrowed money, which totaled approximately $520,800, including all accrued, but unpaid, interest thereon, was converted into 65,591.4971298402 shares of the Company’s newly designated Series C Preferred Stock, 46,699.9368965913 shares of which were issued to Ron Zamber and 18,891.5602332489 shares of which were issued to Greg Johnson (together, “Navitus Shares”).

On August 21, 2017, in connection with the Transaction Agreement, the Company entered into a settlement agreement and mutual release with Ron Zamber and Kim Rubin Hill, pursuant to which all obligations of the Company to Ron Zamber and Kim Rubin Hill to repay indebtedness for borrowed money, which totaled approximately $35,000, including all accrued, but unpaid, interest thereon, was converted into 4,408.03072109140 shares of the Company’s newly designated Series C Preferred Stock,

20



1,889.1560233249000 shares of which were issued to Ron Zamber and 2,518.8746977665000 shares of which were issued to Kim Rubin Hill.

David McCall, our general counsel and a director, is a partner in The McCall Firm. Fees related to his services are attributable to litigation involving the Company’s oil and natural gas operations in Texas. On August 21, 2017, in connection with the Transaction Agreement, the Company entered into a settlement agreement and mutual release (the “McCall Settlement Agreement”) with McCall Law Firm (“McCall”), pursuant to which all obligations of the Company to McCall to repay indebtedness for borrowed money, which totaled $380,323, including all accrued, but unpaid, interest thereon, was converted into 20,000 shares (the “McCall Shares”) of the Company’s newly designated Series D Preferred Stock. As of September 30, 2017 and December 31, 2016, the Company owed The McCall Firm $0 and $503,377, respectively.

On August 21, 2017 the Company entered into a loan agreement (the “Loan Agreement”) with VPEG pursuant to which VPEG loaned $500,000 to the Company. Such loan is evidenced by a secured convertible original issue discount promissory note (the “VPEG Note”) issued by the Company to VPEG on August 21, 2017. The VPEG Note reflects an original issue discount of $50,000 such that the principal amount of the VPEG Note is $550,000, notwithstanding the fact that the loan is in the amount of $500,000. The VPEG Note does not bear any interest in addition to the original issue discount; provided that upon the occurrence of an event of default (as defined in the VPEG Note), interest upon the unpaid principal amount shall begin to accrue at a rate equal to the lesser of (i) eight percent (8%) per annum or (ii) the maximum interest rate allowed from time to time under applicable law. The VPEG Note was to mature on September 1, 2017 and is secured by a security interest in all of the Company’s assets. VPEG has the right, exercisable at any time prior to payment in full, to convert all or any portion of the principal amount then outstanding, plus all accrued but unpaid interest, into shares of the Company’s common stock at a conversion price equal to $0.04 per share, subject to adjustment.

During the nine months ended September 30, 2017, advances totaling $65,000 were made by VPEG. Mr. Ronald Zamber, one of the Company's directors, is the Managing Director and Chairman of VPEG. These amounts are recorded in Accrued liabilities - related parties as of September 30, 2017. As described further in Note 9 - Subsequent Events, per an amendment to the Loan Agreement and Note (the “Amendment”), these advances became part of the increased loan amount.

Note 7 – Shareholders’ Equity
 
Preferred stock

The Company is authorized to issue 2,500,000 shares of $0.001 par value preferred stock. The company has designated 200,000 shares of its preferred stock as Series A Preferred Stock, 800,000 shares as Series B Preferred Stock, 810,000 shares as Series C Preferred Stock and 20,000 shares as Series D Preferred Stock and 670,000 shares of Preferred Stock remain undesignated. The Company has 1,000,000 shares of preferred stock issued and outstanding as of September 30, 2017.

The terms of the Series B Convertible Preferred Stock are governed by a certificate of designation (the “Series B Certificate of Designation”) filed by the Company with the Nevada Secretary of State on August 21, 2017. Pursuant to the Series B Certificate of Designation, the Company designated 800,000 shares of its preferred stock as Series B Convertible Preferred Stock. 

On August 21, 2017, Victory Energy Corporation (the “Victory”) entered into a transaction agreement (the “Transaction Agreement”) with Armacor Victory Ventures, LLC, a Delaware limited liability company (“Armacor”), pursuant to which Armacor (i) granted to Victory a worldwide, perpetual, royalty free, fully paid up and exclusive sublicense (the “License”) to all of Armacor’s owned and licensed intellectual property for use in the Oilfield Services Business (as defined in the Transaction Agreement), and (ii) agreed to contribute to Victory $5,000,000 (the “Cash Contribution”), in exchange for which the Company issued 800,000 shares (the “Armacor Shares”) of its newly designated Series B Convertible Preferred Stock. The closing of the Transaction Agreement (the “Closing”) also occurred on August 21, 2017.

On the later to occur of (i) the date on which all Funding Conditions (as defined in the Transaction Agreement) have been satisfied, and (ii) the date that Armacor Victory Ventures, LLC pays the Company the entire Cash Contribution (as defined in the Transaction Agreement) in accordance with the Transaction Agreement (the "Conversion Date"), each share of Preferred B Stock plus accrued, but unpaid, dividends thereon shall be automatically converted into such number of fully paid and non-assessable shares of Common Stock as is determined by dividing the Stated Value by the Conversion Price in effect on the Conversion Date. The "Conversion Price" shall initially be equal to $0.04. Such initial Conversion Price, and the rate at which shares of Preferred B Stock plus accrued, but unpaid dividends thereon, may be converted into shares of Common Stock, shall be subject to adjustment as provided in Exhibit A of the the Series B Certificate of Designation.

The terms of the Series C Preferred Stock are governed by a certificate of designation (the “Series C Certificate of Designation”) filed by the Company with the Nevada Secretary of State on August 21, 2017. Pursuant to the Series C Certificate of Designation, the Company designated 810,000 shares of its preferred stock as Series C Preferred Stock. 

As discussed in Note 6 – Related Party Transactions, On August 21, 2017, the Company entered into the VPEG Settlement Agreement, the Navitus Settlement Agreement and the Insider Settlement Agreement pursuant to which the Company issued 180,000 shares of the Company’s newly designated Series C Preferred Stock.

On the date on which all Funding Conditions (as defined in the Transaction Agreement) have been satisfied (the "Conversion Date"), each share of Preferred C Stock plus accrued, but unpaid, dividends thereon shall be automatically converted into such number of fully paid and non-assessable shares of Common Stock as is determined by dividing the Stated Value by the Conversion Price in effect on the Conversion Date. The "Conversion Price" shall initially be equal to $0.04. Such initial Conversion Price, and the rate at which shares of Preferred C Stock plus accrued, but unpaid dividends thereon, may be converted into shares of Common Stock, shall be subject to adjustment as provided in Exhibit A of the the Series C Certificate of Designation.

The terms of the Series D Preferred Stock are governed by a certificate of designation (the “Series D Certificate of Designation”) filed by the Company with the Nevada Secretary of State on August 21, 2017. Pursuant to the Series D Certificate of Designation, the Company designated 20,000 shares of its preferred stock as Series D Preferred Stock. 

As discussed in Note 6 – Related Party Transactions, On August 21, 2017, the Company entered into the McCall Settlement Agreement pursuant to which the Company issued 20,000 shares of the Company’s newly designated Series D Preferred Stock.

If, following the date when Shareholder Approval (as defined in the Transaction Agreement) has been obtained, any portion of the Redemption Price has not been paid by the Company on any Redemption Date, the Holder of Series D Preferred Stock may, at its option, elect to convert each share of Preferred D Stock plus accrued, but unpaid dividends thereon, into such number of fully paid and non-assessable shares of Common Stock as is determined by dividing the Stated Value by the Conversion Price in effect on the Conversion Date; provided, however, that in lieu of such conversion and before giving effect thereto, the Company may elect to bring current the redemption payments payable under Section 6 of Exhibit A of the the Series D Certificate of Designation. The "Conversion Price" shall initially be equal to $0.04. Such initial Conversion Price, and the rate at which shares of Preferred D Stock plus accrued, but unpaid dividends thereon, may be converted into shares of Common Stock, shall be subject to adjustment as provided in Exhibit A of the the Series D Certificate of Designation.

Common stock
 
The Company is authorized to issue 47,500,000 shares of $0.001 par value common stock, and has 31,220,326 shares of common stock outstanding as of September 30, 2017.

During the three months ended September 30, 2017 the Company issued 7,500,000 options to purchase shares of common stock to an employee with an exercise price of $0.04. The options vest ratably over 36 months.

During the nine months ended September 30, 2017 the Company issued 2,640,000 warrants to purchase shares of common stock to directors, officers and employees for 2016 services with an exercise price of $0.06. During the nine months ended September 30, 2017 the Company issued 5,203,252 warrants to purchase shares of common stock to Visionary Private Equity Group I, LP at an exercise price of $0.0923. During the nine months ended September 30, 2017 the Company issued 2,044,679 warrants to purchase shares of common stock to a vendor in exchange for services rendered at an exercise price of $0.04. During the nine months ended September 30, 2017 the Company issued 1,170,000 warrants to purchase shares of common stock to Navitus at exercise prices ranging from $0.04 - $0.09. During the nine months ended September 30, 2016 the Company issued 1,372,000 warrants to Navitus with an exercise price ranging from $0.15 - $0.21. These warrants to purchase shares of common stock were issued in consideration of capital contributions to Aurora pursuant to the Company's capital contribution agreement with Aurora. The warrants vest immediately.

Note 8 - Commitments and Contingencies

Contingencies
 
Liabilities and other contingencies are recognized upon determination of an exposure, which when analyzed indicates that it is both probable that an asset has been impaired or that a liability has been incurred and that the amount of such loss is reasonably estimable.

Volatility of Oil and Natural Gas Prices
 
Our revenues, future rate of growth, results of operations, financial condition and ability to borrow funds or obtain additional capital, as well as the carrying value of our properties, are substantially dependent upon prevailing prices of oil and natural gas.



21



Litigation

Legal Cases Settled
 
Cause No. 08-04-07047-CV; Oz Gas Corporation v. Remuda Operating Company, et al. v. Victory Energy Corporation.; In the 112th District Court of Crockett County, Texas.

Plaintiff Oz Gas Corporation (“Oz”) filed a lawsuit in April 2008 against various parties for bad faith trespass, among other claims, regarding the drilling of two wells on lands that Oz claims title to. On November 18, 2009, Victory Energy Corporation intervened in the lawsuit to protect its fifty percent (50%) interest in one of the named wells in the lawsuit (that being the 155-2 well located on the Adams Baggett Ranch in Crockett County, Texas).

This case was mediated, with no settlement reached. It went to trial February 8-9, 2012. The Court found in favor of Oz and rendered verdict against Victory and the other Defendants, jointly and severally. Victory appealed this case to the 8th Court of Appeals in El Paso, Texas where the Court of Appeals affirmed the verdict of the District Court and Victory filed a Motion for Rehearing, which was denied. Victory filed a Petition for Review in the Supreme Court of Texas on December 15, 2014, which was denied. Victory filed a Motion for Rehearing with the Supreme Court which was denied. Oz then filed Interrogatories and Request for Production in Aid of Judgment, which were answered by Victory.

A Settlement and Forbearance Agreement was entered into on March 22, 2016, between the parties wherein no further post-judgment discovery or collection efforts will be made by Oz, for $140,000 net of a $14,000 payment received by the Oz receiver (see next following Cause No. C-1-CV-16-001610), with monthly payments of $7,500 commencing April 15, 2016. The balance was fully paid as of September 30, 2017.

Cause No. C-1-CV-16-001610; Oz Gas Corporation v. Victory Energy Corporation; In the County Court at Law No. 1 of Travis County, Texas.

Plaintiff Oz Gas Corporation (“Oz”) filed an Application for Turnover Relief in Travis County, Texas on February 19, 2016. This order was granted and Thomas L. Kolker was appointed as Receiver to assist in the collection of non-exempt assets. Victory itself has not been placed into Receivership. Victory filed its Motion to Vacate the Turnover that was heard and denied by the trial court. Oz has since filed an Amended Application for Turnover Relief and Appointment of a Receiver to be heard March 10, 2016. Victory filed its Notice of Appeal March 4, 2016.
A Settlement and Forbearance Agreement was entered into on March 22, 2016 as described above.
Cause No. D-1-GN-13-000044; Aurora Energy Partners and Victory Energy Corporation v. Crooked Oaks, LLC; In the 261st District Court of Travis County, Texas.

Victory Energy Corporation sued Crooked Oaks, LLC a/k/a Crooked Oak, LLC for breach of a purchase and sale agreement dated May 7, 2012 in which Victory sold certain assets to Crooked Oaks, LLC for $400,000 of which only $200,000 has been paid as of December 31, 2014. The lawsuit seeks to recover the remaining balance owed of $200,000 from Crooked Oaks, LLC in addition to attorney’s fees and all costs of court. Crooked Oaks, LLC has asserted a counterclaim for rescission of the underlying contract.

Victory and Crooked Oaks attended a mediation on February 10, 2016 where it was determined that Crooked Oaks was insolvent and since that date the case has been dismissed with prejudice.

Cause No. 50916; Trilogy Operating Inc. v. Aurora Energy Partners; In the 118th Judicial District Court of Howard County, Texas.

This lawsuit was filed on January 6, 2016. This lawsuit alleges causes of action for a suit on a sworn account, breach of contract and a suit to foreclose on liens regarding the drilling and completion of seven wells. Aurora filed an answer on January 29, 2016. Trilogy filed a Motion for Partial Summary Judgment on March 23, 2016.

The parties entered into a Settlement Agreement and Release on April 26, 2016, effective April 1, 2016 to dismiss the lawsuit with prejudice. The court granted the Joint Motion to Dismiss with Prejudice on May 2, 2016. In conjunction with the Joint Motion to Dismiss, Aurora assigned Trilogy all of its interests in the seven wells and related oil and gas leases.


22



Cause No. 2015-05280; TELA Garwood Limited, LP. v. Aurora Energy Partners, Victory Energy Corporation, Kenneth Hill, David McCall, Robert Miranda, Robert Grenley, Ronald Zamber, and Patrick Barry; In the 164th District Court of Harris County, Texas.
This lawsuit was filed on January 30, 2015 and supplemented on March 4, 2015. This lawsuit alleges breach of contract regarding a Purchase and Sale Agreement that TELA Garwood Limited, LP and Aurora Energy Partners entered into on June 30, 2014. A first closing was held on June 30, 2014 and a purchase price adjustment payment was made on July 31, 2014. Between these two dates, Aurora paid TELA approximately $3,050,133. A second closing was to take place in September, however several title defects were found to exist. The title defects could not be cured and a purchase price reduction could not be agreed upon by the parties in relation to the title defects, therefore, the second closing never took place. Aurora and Victory filed an answer and counterclaim in this case. Both parties filed opposing motions for summary judgment which were heard on April 14, 2016. The Court granted Aurora's partial motions for summary judgment dismissing claims against Aurora/Victory's officers and directors, including Kenny Hill, David McCall, Robert Grenley, Ronald Zamber, Patrick Barry, and Fred Smith. The Court denied the remaining summary judgment issues of both parties. On June 2, 2016 Aurora/Victory filed a second Motion for Partial Summary Judgment on some discrete contract interpretation issues. The Court denied this motion on September 2, 2016.
On December 9, 2016, Aurora/Victory and TELA entered into a Mutual Release and Settlement Agreement in which Aurora agreed to pay TELA $320,000 and in turn each Party agreed to release the other Party from any matter relating to the Purchase and Sale Agreement, the litigation or any claims that were or could have been brought in the litigation. In accordance with the Mutual Release and Settlement Agreement, Aurora made the full payment on February 1, 2017.
Cause No. 10-09-07213; Perry Howell, et al. v. Charles Gary Garlitz, et al.; In the 112th District Court of Crockett County, Texas.
The above referenced lawsuit was filed on or about September 6, 2010. This lawsuit alleges that Cambrian Management, Ltd. and Victory were trespassers on their land, and that they, along with other Defendants, drilled a well (115 #8) on land belonging to Plaintiffs. Plaintiffs claim trespass and unjust enrichment by certain Defendants because of the drilling of the 115 #8 well.
The Court placed this case on the Dismissal Docket asking any party to show cause as to why it should maintain this case on the docket on July 8, 2016. No party came forward stating why the case should be maintained and the Court entered and Order of Dismissal on August 9, 2016.
Legal Cases Pending

Cause No. CV-47230; James Capital Energy, LLC and Victory Energy Corporation v. Jim Dial, et al.; In the 142nd District Court of Midland County, Texas.

This is a lawsuit filed on or about January 19, 2010, by James Capital Energy, LLC and Victory Energy Corporation against numerous parties for fraud, fraudulent inducement, negligent misrepresentation, breach of contract, breach of fiduciary duty, trespass, conversion and a few other related causes of action. This lawsuit stems from an investment Victory made involving the purchase of six wells on the Adams Baggett Ranch with the right of first refusal on option acreage.

On December 9, 2010, Victory was granted an interlocutory Default Judgment against Defendants Jim Dial, 1st Texas Natural Gas Company, Inc., Universal Energy Resources, Inc., Grifco International, Inc., and Precision Drilling & Exploration, Inc. The total judgment amounted to approximately $17,183,987.

Victory has added a few more parties to this lawsuit. Discovery is ongoing in this case and no trial date has been set at this time.

Victory believes it will prevail against all the remaining Defendants in this case.

On October 20, 2011, Defendant Remuda filed a Motion to Consolidate and a Counterclaim against Victory. Remuda is seeking to consolidate this case with two other cases wherein Remuda is the named Defendant. An objection to this motion was filed and the cases have not been consolidated. Additionally, we do not believe that the counterclaim made by Remuda has any legal merit.

Note 9 - Subsequent Events

As discussed in Note 6 - Related Party Transactions, on August 21, 2017, the Company entered into a Loan Agreement with VPEG , pursuant to which VPEG loaned $500,000 to the Company. On October 11, 2017, the Company and VPEG entered into the Amendment, pursuant to which the parties agreed to (i) increase the loan amount to $565,000, (ii) increase the principal amount of the Note to $621,500, reflecting an original issue discount of $56,500 and (iii) extend the maturity date to November 30, 2017. In addition, VPEG has the option, but not the obligation, to loan to the Company up to an additional $250,000 on the terms specified in the Loan Agreement. During the period of October 1, 2017 through November 14, 2017 the Company received additional loan proceeds of $145,000.

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
The following discussion is intended to assist you in understanding our business and results of operations together with our present financial condition. This section should be read in conjunction with: (i) our condensed consolidated financial statements and the accompanying notes included elsewhere in this Quarterly Report on Form 10-Q; and (ii) our Annual Report on Form 10-K for the year ended December 31, 2016 ("2016 Form 10-K"). Statements in our discussion may be forward-looking statements. These forward-looking statements involve risks and uncertainties. We caution that a number of factors could cause future production, revenues and expenses to differ materially from our expectations.
 
The following is management’s discussion and analysis of certain significant factors that have affected certain aspects of our financial position and results of operations during the periods included in the accompanying unaudited condensed consolidated financial statements.
 
General Overview
 
We are an Austin, Texas based publicly held oil and gas exploration and production company that is in the process of transitioning to an oilfield services business. The Company was organized under the laws of the State of Nevada on January 7, 1982. On August 21, 2017 we entered into a transaction and investment agreement (the “Transaction Agreement”), sublicense agreement and other related agreements with Armacor Victory Ventures, LLC (“AVV”), an affiliate of Armacor Holdings, LLC and Liquidmetal Coatings. As part of the transaction, AVV has granted to Victory a worldwide, perpetual, royalty free, fully paid up and exclusive sublicense (the “License”) to all of AVV’s owned and licensed intellectual property for use in the oilfield services industry, except for a tubular solutions company headquartered in France. The Liquidmetal Coatings - Armacor product line has been widely tested and down-hole validated by several large U.S. based oil and gas companies, who are currently using the product. Previous to entering into the Transaction Agreement, we had been focused on the acquisition and development of unconventional resource play opportunities in the Permian Basin, the Eagle Ford shale of South Texas and other strategically important areas that offer predictable economic outcomes and long-lived reserve characteristics. Our current asset portfolio includes both vertical and horizontal wells in prominent formations such as the Eagle Ford, Austin Chalk, Woodbine, Spraberry, Wolfcamp, Wolfberry, Mississippian, Cline, Fusselman and Ellenberger. As of September 30, 2017, we held a working interest in 30 completed wells located in Texas and New Mexico, predominantly in the Permian Basin of West Texas and the Eagle Ford area of south Texas.

We hold a 50% partnership interest in Aurora Energy Partners ("Aurora"), a Texas partnership, which Aurora controls. Aurora is a consolidated subsidiary with Victory for financial statement purposes. We currently conduct all of our oil and natural gas operations through, and hold all of our oil and natural gas assets through, Aurora. Aurora is the record title-holder to substantially all of the oil and natural gas properties, wells and reserves referred to in this quarterly report. Through our partnership interest in Aurora, we are the beneficial owner of fifty percent (50%) of the oil and gas properties, wells and reserves held of record by Aurora. Victory is one of two partners in Aurora, which was established in January 2008. The second partner in Aurora is the Navitus Energy Group ("Navitus"), a Texas general partnership.

Navitus Partners, LLC, a partner in the Navitus general partnership, raised capital for contribution through Navitus to the Aurora partnership, the net proceeds of which were used to fund Aurora's operations. The investors in this offering received a ten percent (10%) preferred return through their indirect interest in the Navitus partnership for five years and one warrant to purchase one share of Victory common stock for every dollar invested and additional benefits. Under the terms of the offering, Navitus had the right to contribute up to $15 million into Aurora and Victory is obligated to match the capital contribution amount of Navitus resulting from the offering. Victory is also required to match previous contributions made by Navitus. Under the agreement governing the offering, Victory may also raise funds from other sources. Substantially all producing oil and natural gas assets are held in the Aurora partnership during the five year term of the Aurora Partnership Agreement which ended in October 2017. As of September 30, 2017, Navitus has contributed an aggregate of $10.6 million into Aurora.
We will hold a special meeting of our shareholders on November 20, 2017 to obtain their approval of all necessary provisions of the Transaction Agreement (the “Shareholder Approval”) and other Company matters. Upon obtaining Shareholder Approval, this 50% interest and the corresponding producing assets will be conveyed (divested) to Navitus, Aurora’s other 50% interest holder. Also upon Shareholder Approval, AVV is expected to contribute $5 million (the “Cash Contribution”) to us for the development and execution of the sales and distribution business growth plan. Following the shareholder meeting and related divestiture, Victory will remain a public company, which will focus exclusively on Technology-Driven, Friction Reducing Oilfield Products and Services. 




23



Going Concern

The accompanying consolidated financial statements have been prepared assuming we will continue as a going concern, which contemplates the realization of assets and satisfaction of liabilities in the normal course of business. As presented in the consolidated financial statements, we have incurred a net loss of $599,174 and $195,516 for the three months ended September 30, 2017 and 2016, respectively, and net losses of $1,851,725 and $1,180,617 for the nine months ended September 30, 2017 and 2016, respectively.

The cash proceeds from new contributions to the Aurora partnership by Navitus, and loans from affiliates have allowed us to continue operations. We anticipate that operating losses will continue in the near term until we begin to operate as a technology focused oilfield services business. We have invested $0 and $18,442, respectively, in leases, and drilling and completion costs, for the nine months ended September 30, 2017 and 2016, respectively.
On August 21, 2017 we entered into a loan agreement (the “Loan Agreement”) with Visionary Private Equity Group I, LP, a Missouri limited partnership (“VPEG”) pursuant to which VPEG loaned $500,000 to the Company. This loan provided short-term financing required for operating and transaction expenses.

On August 21, 2017, we entered into a Transaction Agreement with AVV, pursuant to which AVV (i) granted to us a worldwide, perpetual, royalty free, fully paid up and exclusive sublicense (the “License”) to all of Armacor’s owned and licensed intellectual property for use in the Oilfield Services Business (as defined in the Transaction Agreement), and (ii) agreed to contribute to the Company $5,000,000 (the “Cash Contribution”), in exchange for which we issued 800,000 shares (the “Armacor Shares”) of our newly designated Series B Convertible Preferred Stock. The cash contribution is expected upon Shareholder Approval and will provide financing for the development and execution of the sales and distribution business growth plan.

The accompanying consolidated financial statements are prepared as if we will continue as a going concern. The consolidated financial statements do not contain adjustments, including adjustments to recorded assets and liabilities, which might be necessary if we were unable to continue as a going concern.

Recently Adopted Accounting Standards

In January 2017, the Financial Accounting Standards Board, or FASB, issued Accounting Standards Update, or ASU, 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business, which changes the definition of a business to assist entities with evaluating when a set of transferred assets and activities is deemed to be a business. Determining whether a transferred set constitutes a business is important because the accounting for a business combination differs from that of an asset acquisition. The definition of a business also affects the accounting for dispositions. Under the new standard, when substantially all of the fair value of assets acquired is concentrated in a single asset, or a group of similar assets, the assets acquired would not represent a business and business combination accounting would not be required. The new standard may result in more transactions being accounted for as asset acquisitions rather than business combinations. The standard is effective for interim and annual periods beginning after December 15, 2017 and shall be applied prospectively. Early adoption is permitted. The Company adopted ASU 2017-01 on January 1, 2017 and will apply the new guidance to applicable transactions going forward.

Factors affecting financial reporting of our general and administrative expenses
 
Our historical general and administrative expenses included in our results of operations for the periods presented may not be comparable, either from period to period or going forward, for the following reasons:
 
Growth-in-business related general expenses
 
As part of our transition to an oilfield service business, the Company incurred costs associated with the Transaction Agreement and other agreements during the quarter ended September 30, 2017. Among other things, these additional general and administrative expenses include legal and professional fees. These specific expenses are not quarterly recurring, however they may occur again due to our acquisition strategy. These expenses were significant, but enabled us to change the strategic direction of the Company. We anticipate that costs related to our transition to an oilfield service business will be significant. We have incurred significant costs to structure and manage our debt facility and will continue to incur such costs until our asset base allows for prudent borrowing. These costs can fluctuate as debt instruments are ended, modified and replaced with new creditor entities.

We have incurred director, employee, and vendor stock based compensation, all non-cash in nature, as part of our key employee acquisition and retention plan. As we grow, we need to add new talent and incentivize our current key employees to stay with the Company. The 2014 Long Term Incentive Plan, approved by our shareholders in February 2014, was a key element of the platform to fulfill this need. Among other things, the Company incurred SEC related legal expenses as part of this plan and shareholder

24



vote. Stock grants and multi-year stock option award based compensation is now a fundamental part of the Company’s key-employee retention plan.

Volume and Price Trends

The following tables summarize the volumes and prices realized by the Company for the three and nine months ended September 30, 2017 compared to the three and nine months ended September 30, 2016.

Overall, Barrel of Oil Equivalent, or BOE, production increased 0% for the three months ended September 30, 2017 and decreased 11% for the nine months ended September 30, 2017. While BOE production for the three months ended September 30, 2017 was relatively flat, there was a 34% decrease in oil production, which was offset by a 62% increase in gas production. BOE production for the nine months ended September 30, 2017 declined by 11% due to a 35% decrease in oil production, which was partially offset by a 36% increase in gas production.

 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2017

 
2016
 
Change

 
2017
 
2016
 
Change
Period Production
 
 
 
 
 
 
 
 
 
 
 
Oil (Bbl)
996

 
1,501
 
(34
)%
 
3,463

 
5,363
 
(35
)%
Gas (Mcf)
7,890

 
4,884
 
62
 %
 
22,870

 
16,762
 
36
 %
BOE
2,311

 
2,315
 
 %
 
7,275

 
8,157
 
(11
)%
Daily Production
 
 
 
 
 
 
 
 
 
 
 
Oil (Bbl/d)
11

 
16
 
(31
)%
 
13

 
20
 
(35
)%
Gas (Mcf/d)
86

 
53
 
62
 %
 
84

 
61
 
38
 %
BOE/d
25

 
25
 
 %
 
27

 
30
 
(10
)%

During the three months ended September 30, 2016 and 2017, the price per barrel realized by the Company increased from $35.82 to $37.65 or 5%, respectively. For the three months ended September 30, 2016 and 2017 the price per Mcf realized by the Company decreased from $3.95 to $2.57 or 35%, respectively.

During the nine months ended September 30, 2016 and 2017, the price per barrel realized by the Company increased from $33.03 to $42.45 or 29%, respectively. For the nine months ended September 30, 2016 and 2017 the price per Mcf realized by the Company increased from $2.45 to $2.92 or 19%, respectively.

 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2017

 
2016

 
Change

 
2017
 
2016
 
Change
Realized Prices
 
 
 
 
 
 
 
 
 
 
 
Oil ($/Bbl)
$
37.65

 
$
35.82

 
5
 %
 
$
42.45

 
$
33.03

 
29
%
Gas ($/Mcf)
2.57

 
3.95

 
(35
)%
 
2.92

 
2.45

 
19
%
Value per BOE
$
25.00

 
$
31.57

 
(21
)%
 
$
29.38

 
$
26.76

 
10
%

The volume and price changes in the tables above caused the following changes to our oil, gas and NGL sales between the three and nine months ended September 30, 2017 and 2016.


25



 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
Oil
Gas
Total
 
Oil
Gas
Total
 
 
 
 
 
 
 
 
2016 Sales
$
53,757

$
19,308

$
73,065

 
$
177,151

$
41,092

$
218,243

Change due to Volumes
(18,077
)
11,883

(6,194
)
 
(62,753
)
14,973

(47,780
)
Change due to Prices
1,823

(10,930
)
(9,107
)
 
32,616

10,665

43,281

2017 Sales
$
37,503

$
20,261

$
57,764

 
$
147,014

$
66,730

$
213,744


The Company’s oil and gas revenue fluctuations are directly related to the volumes produced and the commodity prices paid over the respective periods presented.

Oil and gas sales decreased $6,194 due to volumes in the three months ended September 30, 2017 compared to the three months ended September 30, 2016. The decrease was primarily driven by lower oil production.

Oil and gas sales decreased $9,107 due to prices in the three months ended September 30, 2017 compared to the three months ended September 30, 2016. The decrease was primarily driven by lower market prices for gas.

Oil and gas sales decreased $47,780 due to volumes in the nine months ended September 30, 2017 compared to the nine months ended September 30, 2016. The decrease was primarily driven by lower oil production.

Oil and gas sales increased $43,281 due to prices in the nine months ended September 30, 2017 compared to the nine months ended September 30, 2016. The increase was due to higher market prices for both oil and gas.

Public Company Expenses
 
We incur direct, incremental general and administrative expenses as a result of being a publicly traded company, including but not limited to, increased scope of operations as we evaluate potential acquisitions, corporate structure planning, implementation of stock based compensation programs to attract and retain talent, periodic public reporting to shareholders, tax consulting, independent auditor fees, legal fees, investor relations activities, registrar and transfer fees, director and officer liability insurance, and director compensation. In some cases, our small reporting company status will make key acquisitions and divestitures fall into “significant” status. This requires us to perform a series of financial accounting and reporting processes and filings. As we grow, these transactions will become a smaller part of our overall size, and may no longer be required.

Three Months Ended September 30, 2017 compared to the Three Months Ended September 30, 2016
 
The condensed consolidated operating statements of our revenue, operating expenses, and net income for the three months ended September 30, 2017 as compared to the three months ended September 30, 2016 were as follows:

26



 
 
(Unaudited)
 
 
 
 
 
Three Months Ended
September 30,
 
 
 
Percentage

 
2017

 
2016

 
Change

 
Change

Revenues
 
 
 
 
 
 
 
Oil and gas sales
$
57,764

 
$
73,065

 
$
(15,301
)
 
(21
)%
Total revenues
57,764

 
73,065

 
(15,301
)
 
(21
)%
Operating Expenses:
 
 
 
 
 

 
 

Lease operating costs
13,145

 
20,585

 
(7,440
)
 
(36
)%
Production taxes
3,322

 
4,097

 
(775
)
 
(19
)%
General and administrative
510,636

 
190,675

 
319,961

 
168
 %
Depreciation, depletion, amortization and accretion
29,916

 
32,729

 
(2,813
)
 
(9
)%
Total operating expenses
557,019

 
248,086

 
308,933

 
125
 %
Loss from operations
(499,255
)
 
(175,021
)
 
(324,234
)
 
185
 %
Other Income (Expense):
 
 
 

 
 

 
 

Management fee income
869

 
772

 
97

 
13
 %
Interest expense
(106,742
)
 
(33,300
)
 
73,442

 
221
 %
Total other income and expense
(105,873
)
 
(32,528
)
 
73,345

 
225
 %
Loss before Tax Benefit
(605,128
)
 
(207,549
)
 
397,579

 
192
 %
Tax benefit

 

 

 
 %
Net loss
(605,128
)
 
(207,549
)
 
397,579

 
(192
)%
Less: Net loss attributable to non-controlling interest
(5,954
)
 
(12,033
)
 
(6,079
)
 
(51
)%
Net Loss Attributable To Victory Energy Corporation
$
(599,174
)
 
$
(195,516
)
 
$
403,658

 
206
 %

Oil and gas sales: Our revenues decreased $15,301 or 21% to $57,764 for the three months ended September 30, 2017 from $73,065 for the three months ended September 30, 2016. The decrease is primarily the result of lower oil volumes.

Lease operating costs: Lease operating expenses decreased $7,440 or 36% to $13,145 for the three months ended September 30, 2017 from $20,585 for the three months ended September 30, 2016. The decrease is primarily the result of lower operating costs on the Penn Virginia wells.

Production taxes: Production taxes are charged at the well head on the value of production of oil and natural gas. Production taxes decreased 19% during the three months ended September 30, 2017 compared to the three months ended September 30, 2016, which is relatively consistent with the decrease in revenues during the period.

General and administrative: General and administrative expenses increased $319,961 or 168% to $510,636 for the three months ended September 30, 2017 from $190,675 for the three months ended September 30, 2016. The increase is primarily due costs associated with the Transaction Agreement, sublicense agreement and other related agreements.

Depletion, depreciation, amortization and accretion: Depletion, depreciation, amortization and accretion decreased $2,813 or 9% to $29,916 for the three months ended September 30, 2017 from $32,729 for the three months ended September 30, 2016. The decrease is primarily due to lower depletion costs in 2017 due to lower oil production.

Management fee income: Management fee income increased $97 or 13% to $869 for the three months ended September 30, 2017. Victory charges a two percent (2%) management fee to Navitus Energy Group, a fifty percent (50%) partner of Aurora, on gross revenues attributable to Aurora. The increase is due to higher revenues attributable to Aurora.

Interest expense: Interest expense increased $73,442 or 221% for the three months ended September 30, 2017 from $33,300 for the three months ended September 30, 2016. The increase is primarily due to two notes payable - affiliate.


27



Tax benefit: There is no provision for income tax or tax benefit recorded for either the three months ended September 30, 2017 or September 30, 2016 due to the net operating loss carry forwards (NOLs) through the period ending September 30, 2017. Accordingly, the Company has recorded a full valuation allowance against its net deferred tax assets. Our NOLs generally begin to expire in 2025.

Nine Months Ended September 30, 2017 compared to the nine Months Ended September 30, 2016
 
 
 
 
 
 
 
 
 
 
(Unaudited)
 
 
 
 
 
Nine Months Ended September 30,
 
 
 
Percentage
Change
 
2017
 
2016
 
Change
 
Inc (Dec)
Revenues
 
 
 
 
 
 
 
Oil and gas sales
213,744

 
218,243

 
$
(4,499
)
 
(2
)%
Gain on settlement and sale of oil and gas properties

 
64,824

 
(64,824
)
 
(100
)%
Total revenues
213,744

 
283,067

 
(69,323
)
 
(24
)%
Operating Expenses:
 
 
 
 
 
 
 
Lease operating costs
70,885

 
83,712

 
(12,827
)
 
(15
)%
Exploration and dry hole costs
2,218

 

 
2,218

 
100
 %
Production taxes
11,813

 
11,152

 
661

 
6
 %
General and administrative
1,628,124

 
1,258,833

 
369,291

 
29
 %
Depreciation, depletion, amortization and accretion
92,216

 
109,016

 
(16,800
)
 
(15
)%
Total operating expenses
1,805,256

 
1,462,713

 
342,543

 
23
 %
Loss from operations
(1,591,512
)
 
(1,179,646
)
 
(411,866
)
 
35
 %
Other Income (Expense):
 
 
 
 

 

Management fee income
2,768

 
3,413

 
(645
)
 
(19
)%
Interest expense
(294,733
)
 
(99,613
)
 
195,120

 
196
 %
Total other income and expense
(291,965
)

(96,200
)
 
195,765

 
203
 %
Loss before Tax Benefit
(1,883,477
)
 
(1,275,846
)
 
607,631

 
48
 %
Tax benefit

 

 

 
 %
Net loss
(1,883,477
)
 
(1,275,846
)
 
607,631

 
48
 %
Less: Net income (loss) attributable to non-controlling interest
(31,752
)
 
(95,229
)
 
63,477

 
67
 %
NET LOSS ATTRIBUTABLE TO VICTORY ENERGY CORPORATION
$
(1,851,725
)
 
$
(1,180,617
)
 
$
671,108

 
57
 %

Oil and gas sales: Our revenues decreased $4,499 or 2% to $213,744 for the nine months ended September 30, 2017 from $218,243 for the nine months ended September 30, 2016. The decrease is primarily the result of a decrease in oil production which was partially offset by an increase in natural gas production and increases in commodity prices of both oil and natural gas.

Gain on settlement and sale of oil and gas properties: The $64,824 decrease in the gain on settlement and sale of oil and gas properties is due to no properties being sold or legally settled for the nine months ended September 30, 2017.

Lease operating costs: Lease operating expenses decreased $12,827 to $70,885 or 15% for the nine months ended September 30, 2017 from $83,712 for the nine months ended September 30, 2016. The decrease is primarily the result of a refund and lower operating costs on the Penn Virginia wells.

Exploration and dry hole costs: Exploration expense increased $2,218 or 100% from $0 for the nine months ended September 30, 2017 compared to the nine months ended September 30, 2016. The increase in exploration expense is primarily the result of geological and geophysical (G&G) costs associated with the services related to acquisition and divestiture work.

Production taxes: Production taxes are charged at the well head on the value of production of oil and natural gas. Production taxes increased $661 or 6% to $11,813 for the nine months ended September 30, 2017 from $11,152 for the nine months ended September 30, 2016. The increase in production taxes is due to timing differences.


28



General and administrative: General and administrative expenses increased $369,291 or 29% to $1,628,124 for the nine months ended September 30, 2017 from $1,258,833 for the nine months ended September 30, 2016. The increase is primarily due to professional service fees and stock compensation expense and costs associated with the Transaction Agreement, sublicense agreement and other related agreements.

Depletion, depreciation, amortization and accretion: Depletion, depreciation, amortization and accretion decreased $16,800 or 15% to $92,216 for the nine months ended September 30, 2017 from $109,016 for the nine months ended September 30, 2016. The decrease is primarily due to a decrease in depletion in 2017.

Management fee income: Management fee income decreased $645 or 19% to $2,768 for the nine months ended September 30, 2017. Victory charges a two percent (2%) management fee to Navitus Energy Group, a fifty percent (50%) partner of Aurora, on gross revenues attributable to Aurora. The decrease is due to lower revenues attributable to Aurora.

Interest expense: Amortization of debt financing costs and interest expense increased $195,120 or 196% for the nine months ended September 30, 2017 from $99,613 of interest income (net) for the nine months ended September 30, 2016. The increase is primarily due to two notes payable - affiliate issued in 2017.

Tax benefit: There is no provision for income tax or tax benefit recorded for either the nine months ended September 30, 2017 or for the nine months ended September 30, 2016 due to the NOLs through the period ending September 30, 2017. Accordingly, the Company has recorded a full valuation allowance against its net deferred tax assets. Our NOLs generally begin to expire in 2025.

Liquidity and Capital Resources
 
Our cash, total current assets, total assets, total current liabilities, and total liabilities as of September 30, 2017 as compared to December 31, 2016, are as follows:
 
 
September 30,
2017
 
December 31,
2016
Cash
$
10,630

 
$
56,456

Total current assets
$
266,309

 
$
248,342

Total assets
$
18,452,147

 
$
885,675

Total current liabilities
$
1,679,068

 
$
3,307,419

Total liabilities
$
1,708,756

 
$
3,314,560

 
At September 30, 2017, the Company had a working capital deficit of $1,412,759 compared to a working capital deficit of $3,059,077 at December 31, 2016. Current liabilities decreased to $1,679,068 at September 30, 2017 from $3,307,419 at December 31, 2016. The decrease is primarily due to payments made to our Lender and conversion of related party payables into preferred stock.

Cash proceeds from new contributions to the Aurora partnership by Navitus, and loans from affiliates have allowed the Company to continue operations and enter into a Transaction Agreement, sublicense agreement and other related agreements that will allow the Company to transition its business into a technology focused oilfield services company. Management anticipates that operating losses will continue in the near term until the Company begins to operate as a technology focused oilfield services company.

On August 21, 2017 we entered into a loan agreement (the “Loan Agreement”) with Visionary Private Equity Group I, LP, a Missouri limited partnership (“VPEG”) pursuant to which VPEG loaned $500,000 to the Company. This loan provided short-term financing required for operating and transaction expenses.

On August 21, 2017, we entered into a Transaction Agreement with Armacor, pursuant to which Armacor (i) granted to us a worldwide, perpetual, royalty free, fully paid up and exclusive sublicense (the “License”) to all of Armacor’s owned and licensed intellectual property for use in the Oilfield Services Business (as defined in the Transaction Agreement), and (ii) agreed to contribute to the Company $5,000,000 (the “Cash Contribution”), in exchange for which we issued 800,000 shares (the “Armacor Shares”) of our newly designated Series B Convertible Preferred Stock. The Cash contribution is expected upon Shareholder Approval and will provide financing for the development and execution of the sales and distribution business growth plan.

Operating Activities


29



Net cash used in operating activities for the nine months ended September 30, 2017 was $1,468,587 after the net loss of $1,883,477 was decreased by $539,810 in non-cash charges and offset by $124,920 in changes to the other operating assets and liabilities. This compares to cash used in operating activities for the nine months ended September 30, 2016 of $1,350,357 after the net loss for that period of $1,275,846 and $221,391 in changes to other operating assets and liabilities were decreased by $146,880 in non-cash charges.
 
Investing Activities

Net cash provided by investing activities for the nine months ended September 30, 2017 was $3,261 due to revisions to furniture and fixtures compared to net cash used in investing activities of $10,148 for the nine months ended September 30, 2016 all of which was used for acquisitions, leases, drilling and related costs net of proceeds from sale of assets.

Financing Activities

Net cash provided by financing activities for nine months ended September 30, 2017 was $1,419,500 primarily relates to contributions from Navitus and proceeds from note payable affiliate which were partially offset by principal payments on debt. This compares to $1,372,000 of contributions from Navitus offset by $8,000 of principal payments on the debt financing for the nine months ended September 30, 2016.

Off-Balance Sheet Arrangements

We have no off-balance sheet arrangements that have or are reasonably likely to have a current of future effect on our financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.

Item 3. Qualitative and Quantitative Discussions about Market Risk
 
As a smaller reporting company we are not required to provide the information required by this Item. However, we did include market risk factors in our Annual Report on Form 10-K for the year ended December 31, 2016 filed with the SEC on March 31, 2017.
 
Item 4. Controls and Procedures
 
Evaluation of Disclosure Controls and Procedures
 
We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission’s rules and forms and that such information is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure.
 
Pursuant to Rule 13a-15(e) under the Exchange Act, we carried out an evaluation, with the participation of our management, including the Chief Executive Officer, or CEO (our principal executive officer), and Chief Financial Officer, or CFO (our principal financial officer), of the effectiveness of our disclosure controls and procedures (as defined under Rule 13a-15(e) under the Exchange Act) as of September 30, 2017. Based upon this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were ineffective as of September 30, 2017.

Management’s Report on Internal Control over Financial Reporting
 
Because of its inherent limitations, internal control over financial reporting may not prevent or detect all misstatements. Projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim consolidated financial statements will not be prevented or detected on a timely basis. Management assessed the effectiveness of our internal control over financial reporting as of September 30, 2017. Based on this assessment, management concluded that our internal controls over financial reporting were ineffective as of September 30, 2017.

30



We lack sufficient segregation of duties within accounting functions, which is a basic internal control. Due to our size and nature, segregation of all conflicting duties may not always be possible and may not be economically feasible. However, to the extent possible, the initiation of transactions, the custody of assets and the recording of transactions should be performed by separate individuals. Management evaluated the impact of our failure to have segregation of duties on our assessment of our disclosure controls and procedures and has concluded that the control deficiency represents a material weakness. To address this material weakness, management performs additional analysis and other procedures to ensure that the consolidated financial statements included herein, fairly present, in all material respects, our financial position, results of operations and cash flows for the periods presented.
This Quarterly Report on Form 10-Q does not include an attestation report of our independent registered public accounting firm regarding internal control over financial reporting. Management’s report was not subject to attestation by our registered public accounting firm pursuant to rules of the Securities and Exchange Commission that permit us to provide only our management’s report in this Quarterly Report on Form 10-Q.
Changes in Internal Controls
 
There have been no changes in our internal controls over financial reporting (or deferred in Rule 13a-15(f) under the Securities Exchange Act) that occurred during the nine months ended September 30, 2017 that materially affected, or are reasonably likely to materially affect, our internal controls over financial reporting.


31



Part IIOther Information
 
Item 1. Legal Proceedings

Cause No. 08-04-07047-CV; Oz Gas Corporation v. Remuda Operating Company, et al. v. Victory Energy Corporation.; In the 112th District Court of Crockett County, Texas.

Plaintiff Oz Gas Corporation (“Oz”) filed a lawsuit in April 2008 against various parties for bad faith trespass, among other claims, regarding the drilling of two wells on lands that Oz claims title to. On November 18, 2009, Victory Energy Corporation intervened in the lawsuit to protect its fifty percent (50%) interest in one of the named wells in the lawsuit (that being the 155-2 well located on the Adams Baggett Ranch in Crockett County, Texas).

This case was mediated, with no settlement reached. It went to trial February 8-9, 2012. The Court found in favor of Oz and rendered verdict against Victory and the other Defendants, jointly and severally. Victory appealed this case to the 8th Court of Appeals in El Paso, Texas where the Court of Appeals affirmed the verdict of the District Court and Victory filed a Motion for Rehearing, which was denied. Victory filed a Petition for Review in the Supreme Court of Texas on December 15, 2014 which was denied. Victory filed a Motion for Rehearing with the Supreme Court which was denied. Oz then filed Interrogatories and Request for Production in Aid of Judgment which were answered by Victory.

A Settlement and Forbearance Agreement was entered into on March 22, 2016, between the parties wherein no further post-judgment discovery or collection efforts will be made by Oz, for $140,000 net of a $14,000 payment received by the Oz receiver (see next following Cause No. C-1-CV-16-001610), with monthly payments of $7,500 commencing April 15, 2016. The balance was fully paid as of September 30, 2017.

Cause No. C-1-CV-16-001610; Oz Gas Corporation v. Victory Energy Corporation; In the County Court at Law No. 1 of Travis County, Texas.

Plaintiff Oz Gas Corporation (“Oz”) filed an Application for Turnover Relief in Travis County, Texas on February 19, 2016. This order was granted and Thomas L. Kolker was appointed as Receiver to assist in the collection of non-exempt assets. Victory itself has not been placed into Receivership. Victory filed its Motion to Vacate the Turnover that was heard and denied by the trial court. Oz has since filed an Amended Application for Turnover Relief and Appointment of a Receiver to be heard March 10, 2016. Victory filed its Notice of Appeal March 4, 2016.
A Settlement and Forbearance Agreement was entered into on March 22, 2016 as described above.
Cause No. D-1-GN-13-000044; Aurora Energy Partners and Victory Energy Corporation v. Crooked Oaks, LLC; In the 261st District Court of Travis County, Texas.

Victory Energy Corporation sued Crooked Oaks, LLC a/k/a Crooked Oak, LLC for breach of a purchase and sale agreement dated May 7, 2012 in which Victory sold certain assets to Crooked Oaks, LLC for $400,000 of which only $200,000 has been paid as of December 31, 2014. The lawsuit seeks to recover the remaining balance owed of $200,000 from Crooked Oaks, LLC in addition to attorney’s fees and all costs of court. Crooked Oaks, LLC has asserted a counterclaim for rescission of the underlying contract.

Victory and Crooked Oaks attended a mediation on February 10, 2016 where it was determined that Crooked Oaks was insolvent and since that date the case has been dismissed with prejudice.

Cause No. 50916; Trilogy Operating Inc. v. Aurora Energy Partners; In the 118th Judicial District Court of Howard County, Texas.

This lawsuit was filed on January 6, 2016. This lawsuit alleges causes of action for a suit on a sworn account, breach of contract and a suit to foreclose on liens regarding the drilling and completion of seven wells. Aurora filed an answer on January 29, 2016. Trilogy filed a Motion for Partial Summary Judgment on March 23, 2016.

The parties entered into a Settlement Agreement and Release on April 26, 2016, effective April 1, 2016 to dismiss the lawsuit with prejudice. The Joint Motion to Dismiss with Prejudice was granted by the court May 2, 2016. In conjunction with the Joint Motion to Dismiss, Aurora assigned Trilogy all of its interests in the seven wells and related oil and gas leases.


32



Cause No. 2015-05280; TELA Garwood Limited, LP. v. Aurora Energy Partners, Victory Energy Corporation, Kenneth Hill, David McCall, Robert Miranda, Robert Grenley, Ronald Zamber, and Patrick Barry; In the 164th District Court of Harris County, Texas.
This lawsuit was filed on January 30, 2015 and supplemented on March 4, 2015. This lawsuit alleges breach of contract regarding a Purchase and Sale Agreement that TELA Garwood Limited, LP and Aurora Energy Partners entered into on September 30, 2014. A first closing was held on September 30, 2014 and a purchase price adjustment payment was made on July 31, 2014. Between these two dates Aurora paid TELA approximately $3,050,133. A second closing was to take place in September, however several title defects were found to exist. The title defects could not be cured and a purchase price reduction could not be agreed upon by the parties in relation to the title defects, therefore, the second closing never took place. Aurora and Victory filed an answer and counterclaim in this case. Both parties filed opposing motions for summary judgment, which were heard on April 14, 2016. The Court granted Aurora's partial motions for summary judgment dismissing claims against Aurora/Victory's officers and directors, including Kenny Hill, David McCall, Robert Grenley, Ronald Zamber, Patrick Barry, and Fred Smith. The Court denied the remaining summary judgment issues of both parties. On September 2, 2016 Aurora/Victory filed a second Motion for Partial Summary Judgment on some discrete contract interpretation issues. The Court denied this motion on September 2, 2016.
On December 9, 2016, Aurora/Victory and TELA entered into a Mutual Release and Settlement Agreement in which Aurora agreed to pay TELA $320,000 and in turn each Party agreed to release the other Party from any matter relating to the PSA, the litigation or any claims that were or could have been brought in the litigation. In accordance with the Mutual Release and Settlement Agreement, Aurora made the full payment on February 1, 2017.
Cause No. 10-09-07213; Perry Howell, et al. v. Charles Gary Garlitz, et al.; In the 112th District Court of Crockett County, Texas.
The above referenced lawsuit was filed on or about September 6, 2010. This lawsuit alleges that Cambrian Management, Ltd. and Victory were trespassers on their land, and that they, along with other Defendants, drilled a well (115 #8) on land belonging to Plaintiffs. Plaintiffs claim trespass and unjust enrichment by certain Defendants because of the drilling of the 115 #8 well.
The Court placed this case on the Dismissal Docket asking any party to show cause as to why it should maintain this case on the docket on July 8, 2016. No party came forward stating why the case should be maintained and the Court entered and Order of Dismissal on August 9, 2016.
Legal Cases Pending

Cause No. CV-47230; James Capital Energy, LLC and Victory Energy Corporation v. Jim Dial, et al.; In the 142nd District Court of Midland County, Texas.

This is a lawsuit filed on or about January 19, 2010, by James Capital Energy, LLC and Victory Energy Corporation against numerous parties for fraud, fraudulent inducement, negligent misrepresentation, breach of contract, breach of fiduciary duty, trespass, conversion and a few other related causes of action. This lawsuit stems from an investment Victory made involving the purchase of six wells on the Adams Baggett Ranch with the right of first refusal on option acreage.

On December 9, 2010, Victory was granted an interlocutory Default Judgment against Defendants Jim Dial, 1st Texas Natural Gas Company, Inc., Universal Energy Resources, Inc., Grifco International, Inc., and Precision Drilling & Exploration, Inc. The total judgment amounted to approximately $17,183,987.

Victory has added a few more parties to this lawsuit. Discovery is ongoing in this case and no trial date has been set at this time.

Victory believes it will prevail against all the remaining Defendants in this case.

On October 20, 2011 Defendant Remuda filed a Motion to Consolidate and a Counterclaim against Victory. Remuda is seeking to consolidate this case with two other cases wherein Remuda is the named Defendant. An objection to this motion was filed and the cases have not been consolidated. Additionally, we do not believe that the counterclaim made by Remuda has any legal merit.
 
Item 1A. Risk Factors
 
Except as set forth below, there have been no material changes from the risk factors disclosed in the “Risk Factors” section of the Company’s Annual Report on Form 10-K for the year ended December 31, 2016.
We have substantial liabilities that require that we raise additional financing to support our operations. Such financing may only be available on disadvantageous terms, or may not be available at all. Any new financing could have a substantial dilutive effect on our existing stockholders.
As of September 30, 2017, we had $10,630 of cash, current assets of $266,309, current liabilities of $1,679,068 and a working capital deficit of $1,412,759. Our current liabilities include $1,056,364 of accounts payable and accrued liabilities, some of which are past due, and $550,000 of loans payable that are classified as current because the loan is either evidenced by a note that has matured or is not documented by a note at all. We are currently unable to pay our accounts payable. If any material creditor decides to commence legal action to collect from us, it could jeopardize our ability to continue in business.
We will be required to seek additional debt or equity financing in order to pay our current liabilities and to support our anticipated operations. We may not be able to obtain additional financing on satisfactory terms, or at all, and any new equity financing could have a substantial dilutive effect on our existing stockholders. If we cannot obtain additional financing, we will not be able to achieve the operating activities that we need to cover our costs, and our results of operations would be negatively affected.
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds
 
Unregistered sales of equity securities during the nine months ended September 30, 2017:

During the nine months ended September 30, 2017, we issued 1,170,000 warrants to purchase shares of common stock to Navitus at exercise prices ranging from $0.04 - $0.09. These warrants to purchase shares of common stock were issued in consideration of capital contributions to Aurora of $1,170,000 pursuant to our capital contribution agreement with Aurora.

On February 3, 2017, wee issued 5,203,252 warrants to purchase shares of common stock to Visionary Private Equity Group I, LP at an exercise price of $0.0923 per share. These warrants to purchase shares of common stock were issued in conjunction with the Private Placement discussed in Note 6 to the Condensed Consolidated Financial Statements.

On February 6, 2017, we issued 2,640,000 warrants to purchase shares of common stock to directors, officers and employees for services provided during 2016 with an exercise price of $0.06.

On August 21, 2017, we issued 2,044,679 warrants to purchase shares of common stock to a vendor in exchange for services at an exercise price of $0.04 per share.

On August 21, 2017, we issued 800,000 shares of Series B Convertible Preferred Stock to AVV in exchange for $5,000,000 and a worldwide, perpetual, royalty free, fully paid up and exclusive sublicense to all Armacor's owned and licensed intellectual property for use in the oilfield services industry.

On August 21, 2017, pursuant to a settlement agreement and mutual release, all obligations of the Company to VPEG to repay indebtedness for borrowed money (other than the VPEG Note), which totaled approximately $873,410 was converted into 110,000.472149068 shares of the Company's Series C Preferred Stock.

On August 21, 2017, pursuant to a settlement agreement and mutual release, all obligations to certain affiliates of Navitus to repay indebtedness of borrowed money which totaled approximately $520,800 was converted into 65,591.4971298402 shares of the Company's Series C Preferred Stock.

On August 21, 2017, pursuant to a settlement agreement and mutual release with Ron Zamber and Kim Rubin Hill, all obligations of the Company to Ron Zamber and Kim Rubin Hill to repay indebtedness for borrowed money which totaled approximately $35,000 was converted into 4,408.03072109141 shares of the Company's Series C Preferred Stock.

On August 21, 2017, pursuant to a settlement agreement and mutual release, all obligations of the Company to McCall Law Firm to repay indebtedness for borrowed money which totaled approximately $380.323 was converted into 20,000 shares of the Company's Series D Preferred Stock.
 
We relied on the exemption from registration relating to offerings that do not involve any public offering pursuant to Section 4(2) under the Securities Act of 1933 (the “Act”) and/or Rule 506 of Regulation D of the Act. We believe that each investor had adequate access to information about us through the investor’s relationship with us.
 

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Dividends:
 
Our Credit Agreement with Texas Capital Bank includes certain restrictions on our ability to pay dividends or make other payments or distributions to the holders of our common stock.
 
Item 3. Default Upon Senior Securities
 
There is no information required to be reported under this Item.
 
Item 4. Mine Safety Disclosures
 
Not Applicable.
 
Item 5. Other Information
 
There is no information required to be reported under this Item.

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Item 6. Exhibits
 
(a) Exhibits
 
INSERT EXHIBIT RIDER
3.1
 
 
 
 
3.2
 
 
 
 
3.3
 
 
 
 
3.4
 
 
 
 
10.1
 
 
 
 
10.2
 
 
 
 
10.3
 
 
 
 
10.4
 
 
 
 
10.5
 
 
 
 
10.6
 
 
 
 
10.7
 
 
 
 
10.8
 
 
 
 
10.9
 
 
 
 

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10.10
 
 
 
 
10.11
 
 
 
 
10.12
 
 
 
 
10.13
 
 
 
 
10.14
 
 
 
 
10.15
 
 
 
 
10.16
 
 
 
 
10.17
 
 
 
 
10.18
 
 
 
 
31.1 **
 
 
 
 
31.2 **
 
 
 
 
32.1 **
 
 
 
 
32.2 **
 
 
 
 
101.INS*
 
XBRL Instance Document
 
 
 
101.SCH*
 
XBRL Taxonomy Extension Schema Document
 
 
 
101.CAL*
 
XBRL Taxonomy Extension Calculation Linkbase Document
 
 
 
101.DEF*
 
XBRL Taxonomy Extension Definition Linkbase Document
 
 
 
101.LAB*
 
XBRL Taxonomy Extension Label Linkbase Document
 
 
 

36



101.PRE*
 
XBRL Taxonomy Extension Presentation Linkbase Document
_____________
* XBRL (Extensible Business Reporting Language) information is furnished and not filed or part of a registration statement or prospectus for purposes of Section 11 or 12 of the Securities Act of 1933, as amended, is deemed not filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and otherwise is not subject to liability under these sections.
** Filed herewith.

37



Signature
 
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
 
 
 
 
VICTORY ENERGY CORPORATION
 
 
 
 
 
 
Date:
November 14, 2017
By:
/s/ Kenneth Hill
 
 
 
 
Kenneth Hill
 
 
 
 
Chief Executive Officer and Director
 


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