UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 
Form 10-Q
 
(Mark One)
ý
QUARTERLY REPORT UNDER SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2015
o
TRANSITION REPORT UNDER SECTION 13 OR 15(d) OF THE EXCHANGE ACT
 
For the transition period from _______________ to _______________.
 
Commission file number 002-76219NY
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 Ste 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 ý No o
 
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 ý No o
 
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):
 
Large accelerated filer
o
Accelerated filer
o
Non-accelerated filer
o
Smaller reporting company
ý
(Do not check if a smaller reporting company)
 
 
 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No ý
As of October 29, 2015, there were 30,607,826 shares of common stock, par value $0.001, issued and outstanding.

1



VICTORY ENERGY CORPORATION
QUARTERLY REPORT ON
FORM 10-Q
FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2015,
 
TABLE OF CONTENTS
 
 
 
Page
 
 
 
Part I – Financial Information
 
 
 
 
Item 1.
Financial Statements
 
 
Condensed Consolidated Balance Sheets as of September 30, 2015 (unaudited) and December 31, 2014
 
Condensed Consolidated Statements of Operations for the three and nine months ended September 30, 2015 and 2014 (unaudited)
 
Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2015, and 2014 (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
 
The terms “Victory,” “Company,” “we,” “our,” and “us,” refer to Victory Energy Corporation and its consolidated subsidiaries unless the context suggests otherwise. Substantially all of Victory’s asset interests are held through Aurora Energy Partners ("Aurora"), a Texas general partnership, of which Victory controls as managing partner and consolidates as a subsidiary of Victory. Victory holds a 50% controlling partnership interest in Aurora.

This Quarterly Report on Form 10-Q contains a number of forward-looking statements within the meaning of the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 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.
 
Our actual results, performance or achievements could differ materially from the results expressed in, or implied by, these forward-looking statements. It is not possible to identify all of these risks, uncertainties or assumptions. Among the important factors that could cause actual results to differ materially from those in the forward-looking statements are:
 
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 new capital contributions to Aurora Energy Partners;
challenges in growing our business;
designation of our common stock as a “penny stock” under Securities and Exchange Commission (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;
the volatility of oil and natural gas prices;
the high level of risk associated with drilling for and producing oil and natural gas;
the accuracy of assumptions associated with reserve estimates;
the potential that drilling activities will not yield oil or natural gas in commercial quantities;
potential exploration, production and acquisitions may not maintain revenue levels in the future;
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;
difficulties associated with managing a 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;
our levels of insurance or those of our operators may be insufficient;
the dilutive effect of additional issuances of our common stock, options or warrants;
the results of pending litigation; and
the dissolution of the Aurora partnership agreement.

3




Additionally, the information set forth under the heading “Risk Factors” in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2014, as well as disclosures made under the caption “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Item 2 of this Quarterly Report on Form 10-Q and under the caption “Risk Factors”, in Item 1A of the Quarterly Report on Form 10-Q could cause actual results to differ materially from those in the forward-looking statements. Other unpredictable or unknown factors not discussed in this Quarterly Report on Form 10-Q and other documents filed with the SEC could also cause actual results to differ materially from those in the forward-looking statements. The reader should not place undue reliance on these forward-looking statements, which speak only as of the date of this Quarterly Report on Form 10-Q. Unless legally required, we undertake no obligation to publicly update any forward-looking statements, whether as a result of new information, future events or otherwise.

4



Part IFinancial Information

Item 1. Financial Statements

VICTORY ENERGY CORPORATION AND SUBSIDIARY
CONDENSED CONSOLIDATED BALANCE SHEETS
 
September 30,
2015
 
December 31,
2014
 
(Unaudited)
 
 
ASSETS
 
 
 
Current Assets
 
 
 
Cash
$
112,966

 
$
2,941

Accounts receivable - less allowance for doubtful accounts of $200,000, and $200,000 for September 30, 2015 and December 31, 2014, respectively
24,551

 
41,565

Accounts receivable - affiliates
129,284

 
124,367

Prepaid expenses
3,954

 
21,846

Total current assets
270,755

 
190,719

Fixed Assets
 
 
 

Furniture and equipment
46,883

 
46,883

Accumulated depreciation
(22,813
)
 
(17,965
)
Total furniture and equipment
24,070

 
28,918

 
 
 
 
Oil and gas properties, net of accumulated impairment (successful efforts method)
3,578,864

 
2,838,573

Accumulated depletion, depreciation and amortization
(2,036,467
)
 
(1,942,380
)
Total oil and gas properties, net
1,542,397

 
896,193

Other Assets
 
 
 

Deferred debt financing costs, net
57,266

 
87,883

Total Assets
$
1,894,488

 
$
1,203,713

LIABILITIES AND STOCKHOLDERS' DEFICIT
 
 
 
Current Liabilities
 
 
 

Accounts payable
$
2,173,957

 
$
1,119,896

Accrued liabilities
495,551

 
221,209

Accrued liabilities - affiliates
679,111

 
477,934

Liability for unauthorized preferred stock issued
9,283

 
9,283

   Revolving credit facility
730,000

 
800,000

Asset retirement obligations
14,299

 
3,721

Total current liabilities
4,102,201

 
2,632,043

Other Long Term Liabilities
 
 
 

Asset retirement obligations
33,292

 
40,493

Total long term liabilities
33,292

 
40,493

Total liabilities
4,135,493

 
2,672,536

Stockholders' Deficit
 
 
 

Common stock, $0.001 par value, 47,500,000 shares authorized, 30,607,826 shares and
  29,202,826 shares issued and outstanding for September 30, 2015 and December 31, 2014, respectively
30,608

 
29,203

Additional paid-in capital
35,553,772

 
34,974,441

Accumulated deficit
(43,788,466
)
 
(40,111,826
)
Total Victory Energy Corporation stockholders' deficit
(8,204,086
)
 
(5,108,182
)
Non-controlling interest
5,963,081

 
3,639,359

Total stockholders' deficit
(2,241,005
)
 
(1,468,823
)
Total Liabilities and Stockholders' Deficit
$
1,894,488

 
$
1,203,713


The accompanying notes are an integral part of these condensed consolidated financial statements.
5




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,
 
2015
 
2014
 
2015
 
2014
Oil and Gas Revenues
$
152,448

 
$
173,527

 
$
550,647

 
$
606,487

Operating Expenses:
 

 
 

 
 
 
 

Lease operating expenses
37,279

 
42,154

 
114,296

 
157,786

Production taxes
7,178

 
9,547

 
26,719

 
34,809

Dry hole costs

 
576

 

 
576

Exploration and abandonment costs
(5,611
)
 
27,641

 
(2,120
)
 
51,813

General and administrative expense
941,822

 
656,586

 
3,657,016

 
2,120,214

Impairment of oil and natural gas properties
3,152

 

 
309,539

 

Depletion, depreciation, and amortization
84,423

 
81,952

 
335,437

 
252,024

Total operating expenses
1,068,243

 
818,456

 
4,440,887

 
2,617,222

Loss from Operations
(915,795
)
 
(644,929
)
 
(3,890,240
)
 
(2,010,735
)
Other Income (Expense):
 

 
 

 
 
 
 
Gain on sale of oil and gas properties

 
507

 

 
2,160,099

Management fee income
3,053

 
3,470

 
5,728

 
92,362

Interest expense
(32,220
)
 
(18,631
)
 
(79,406
)
 
(49,639
)
Total net other income and (expense)
(29,167
)
 
(14,654
)
 
(73,678
)
 
2,202,822

Income (Loss) before Tax Benefit
(944,962
)
 
(659,583
)
 
(3,963,918
)
 
192,087

Tax benefit

 

 

 

Net income (loss)
(944,962
)
 
$
(659,583
)
 
(3,963,918
)
 
192,087

Less: Net income (loss) attributable to non-controlling interest
(62,353
)
 
(36,788
)
 
(287,278
)
 
977,997

Net income (loss) attributable to Victory Energy Corporation
$
(882,609
)
 
$
(622,795
)
 
$
(3,676,640
)
 
$
(785,910
)
 
 

 
 

 
 
 
 
Weighted average shares, basic and diluted
 
 
 
 
 
 
 

   Basic
29,776,068

 
28,788,533

 
29,428,000

 
28,154,497

   Diluted
29,776,068

 
28,788,533

 
29,428,800

 
28,154,497

Net income (loss) per share, basic and diluted
 

 
 

 
 
 
 

   Basic
$
(0.03
)
 
$
(0.02
)
 
$
(0.12
)
 
$
(0.03
)
   Diluted
$
(0.03
)
 
$
(0.02
)
 
$
(0.12
)
 
$
(0.03
)
 

The accompanying notes are an integral part of these condensed consolidated financial statements.
6




VICTORY ENERGY CORPORATION AND SUBSIDIARY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOW
(Unaudited) 
 
For the Nine Months Ended September 30,
 
2015
 
2014
CASH FLOWS FROM OPERATING ACTIVITIES
 

 
 

Net income (loss)
$
(3,963,918
)
 
$
192,087

Adjustments to reconcile net income (loss) from operations to net cash used in operating activities
 

 
 

Amortization of debt financing costs
30,617

 
24,380

Accretion of asset retirement obligation
4,593

 
2,686

Gain from sale of oil and gas properties

 
(2,160,099
)
Depletion, depreciation, and amortization
335,437

 
252,024

Impairment of assets
309,539

 

Gain on asset retirement settlement
(3,721
)
 

Stock based compensation
411,527

 
461,237

Restricted stock in exchange for services
169,210

 
51,042

Change in operating assets and liabilities
 

 
 

Accounts receivable
17,014

 
60,001

Accounts receivable - affiliates
(4,917
)
 
(100,570
)
Prepaid expense
17,892

 
16,707

Accounts payable
300,207

 
1,010,123

Accrued liabilities
274,342

 
2,618

Accrued liabilities – affiliates
201,177

 
14,781

Net cash used in operating activities
(1,901,001
)
 
(172,983
)
CASH FLOWS FROM INVESTING ACTIVITIES
 

 
 

Drilling and completion costs
(529,974
)
 
(1,569,514
)
Acquisition of oil and gas properties

 
(3,397,122
)
Proceeds from the sale of assets

 
4,021,000

Purchase of furniture and fixtures

 
(3,710
)
Renewal of leaseholds

 
(22,577
)
Net cash provided by investing activities
(529,974
)
 
(971,923
)
CASH FLOWS FROM FINANCING ACTIVITIES
 

 
 

Non-controlling interest contributions
2,611,000

 
1,140,000

Non-controlling interest distributions

 
(647,421
)
Debt financing costs

 
(122,469
)
          Proceeds from issuance of note payable

 
1,233,000

          Principal payments of debt financing
(70,000
)
 
(433,000
)
Net cash provided by financing activities
2,541,000

 
1,170,110

Net change in cash
110,025

 
25,204

Beginning cash
2,941

 
20,858

Ending cash
$
112,966

 
$
46,062

 
 
 
 
Supplemental cash flow information:
 
 
 
Cash paid:
 
 
 
       Interest
$
32,730

 
$
18,978

Non-cash investing and financing activities:
 
 
 
       Asset retirement obligation incurred
$
2,505

 
$
3,721

       Accrued capital expenditures
$
398,052

 
$

 

The accompanying notes are an integral part of these condensed consolidated financial statements.
7




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

Note 1 – Organization and Summary of Significant Accounting Policies
 
Victory is an independent, growth oriented natural resources company engaged in the acquisition, exploration and production of oil and natural gas properties, through its partnership with Aurora Energy Partners, a Texas general partnership (“Aurora”). Current operations are located onshore primarily in the State of Texas. The Company was organized under the laws of the State of Nevada on January 7, 1982. The Company is authorized to issue 47,500,000 shares of $0.001 par value common stock, and has 30,607,826 shares of common stock outstanding as of September 30, 2015. The Company’s corporate headquarters are located at 3355 Bee Caves Road, Suite 608, Austin, TX 78746.
 
A summary of significant accounting policies followed in the preparation of the accompanying condensed consolidated financial statements is set forth below.
 
Basis of Presentation and Consolidation:
 
Victory is the managing partner of Aurora, and holds a 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 governs the operations of Aurora give Victory effective control of the partnership. The condensed 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 that 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.
 
The accompanying condensed consolidated balance sheet as of December 31, 2014, which has been derived from audited consolidated financial statements, and the accompanying interim condensed consolidated financial statements as of September 30, 2015, for three and nine month periods ended September 30, 2015 and 2014, have been prepared by management pursuant to the rules and regulations of the Securities and Exchange Commission "SEC" for interim financial reporting. These interim condensed consolidated financial statements are unaudited and, in the opinion of management, all adjustments, including normal recurring adjustments necessary to present fairly the consolidated financial condition, results of operations and cash flows of Victory and Aurora as of and for the periods presented in accordance with accounting principles generally accepted in the United States of America “U.S. GAAP”, have been included.
 
Operating results for the nine months ended September 30, 2015 are not necessarily indicative of the results that may be expected for the year ending December 31, 2015 or for any other interim period during such year. Certain information and footnote disclosures normally included in consolidated financial statements prepared in accordance with U.S. GAAP have been omitted in accordance with the rules and regulations of the SEC. The accompanying consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto contained in the Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2014 filed with the SEC on March 31, 2015.

Non-controlling Interests:
 
The Navitus Energy Group, a Texas general partnership (“Navitus”) is a partner with Victory in Aurora. Victory and Navitus each own a 50% partnership interest in Aurora. Victory is the Managing Partner and has contractual authority to manage the business affairs of Aurora.
 
The non-controlling interest in Aurora is held by Navitus. As of September 30, 2015, $5,963,081 was recorded as the equity of the non-controlling interest in our consolidated balance sheets representing the third-party investment in Aurora, with income (losses) attributable to non-controlling interests of ($62,353) and ($36,788) for the three months ended September 30, 2015 and 2014, respectively, and $(287,278) and net income of $977,997 for the nine months ended September 30, 2015 and 2014, respectively. As of December 31, 2014, $3,639,359 was recorded as the equity of the non-controlling interest in our consolidated balance sheets representing the third-party investment in Aurora.


8



Use of Estimates:

The preparation of our condensed consolidated financial statements in conformity with U.S. GAAP requires our 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, cost to abandon oil and natural gas properties, taxes, accruals of capitalized costs, operating costs and production revenue, general and administrative costs and interest, exploration expense, the purchase price allocation on properties acquired, various common stock warrants and option transactions, and 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 associated land and other assets are depleted using a Units of Production methodology based on the proved, developed reserves and calculated on a field basis, based upon reserve reports prepared by an independent petroleum engineer in accordance with SEC rules.

Under the successful efforts method of accounting, the depletion rate is the current period production as a percentage of the total proved producing reserves. The depletion rate is applied to the net book value of property costs to calculate the depletion expense. Proved reserves materially impact depletion expense. If the proved reserves decline, then the depletion rate (the rate at which we record depletion expense) increases, reducing net income.

The net capitalized costs of proved oil and natural gas properties are subject to an impairment test which compares the net book value of assets, based on historical cost, to the undiscounted future cash flow of remaining oil and natural gas reserves based on current economic and operating conditions. Impairment of an individual producing oil and natural gas field is first determined by comparing the undiscounted future net cash flows associated with the proved property to the carrying value of the underlying property. If the cost of the underlying property is in excess of the undiscounted future net cash flows the carrying cost of the impaired property is compared to the estimated fair value and the difference is recorded as an impairment loss. Management’s estimate of fair value takes into account many factors such as the present value discount rate, pricing, and when appropriate, possible and probable reserves when activities justified by economic conditions and actual or planned drilling or other development. 
 
We depreciate other property and equipment using the straight-line method based on estimated useful lives ranging from five to 10 years.

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. U.S. GAAP requires that our estimate of our asset retirement obligations does not give consideration to the value the related assets could have to other parties.

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 earnings per share 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 ASC 260, "Earnings per Share", awards of unnvested 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.


9



Income Taxes:
 
The Company accounts for income taxes in accordance with 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 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, 2015 and December 31, 2014. 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 and Expense:
 
The Company applies ASC 718, “Compensation-Stock Compensation” to account for the issuance of options and warrants to employees, 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 life 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.
 
The Company recognized stock-based directors compensation expense from stock awards granted to directors for services of $348,174 and $365,675 for the nine months ended September 30, 2015 and 2014, respectively.
 
The Company recognized stock-based incentive compensation expense from stock options granted to officers and employees of the company of $63,353 and $95,562 for the nine months ended September 30, 2015 and 2014, respectively.

The Company also recognized stock-based general and administrative expense of $169,210 and $51,042 from restricted stock and stock options issued to consultants for the nine months ended September 30, 2015 and 2014, respectively.

New Accounting Pronouncements:

In July 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2015-11, "Inventory (Topic 330): Simplifying the Measurement of Inventory." ASU 2015-11 requires an entity to measure inventory at the lower of cost and net realizable value rather than lower of cost or market as previously required by GAAP. ASU 2015-11 is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. This update should be applied prospectively with early application permitted. The Company is currently evaluating the new guidance and has not determined the impact this standard may have on its financial statements.

In April 2015, the FASB issued ASU 2015-03, "Interest-Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs." ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. Currently, debt issuance costs are recognized as deferred charges and recorded as assets. The guidance is effective for annual and interim periods beginning after December 15, 2015 with early adoption permitted and is to be implemented retrospectively. Adoption of the new

10



guidance will only affect the presentation of debt and deferred debt financing costs in the Company's consolidated balance sheets and will not have a material impact.

Going Concern:
 
The accompanying condensed 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. 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.

As presented in the condensed consolidated financial statements, the Company is reporting net losses, attributable to Victory Energy Corporation, of $882,609 and $622,795 for the three months ended September 30, 2015 and 2014, respectively, and net losses of $3,676,640 and $785,910 for the nine months ended September 30, 2015 and 2014, respectively.

Our total cash and cash equivalents were $112,966 at September 30, 2015. We have been, and anticipate that we will continue to be, limited in terms of our capital resources. We generally have not had enough cash or sources of capital to pay our accounts payable and expenses as they arise. We will be required to raise substantial additional capital to meet our existing payment obligations and to expand our operations.
Proceeds from Navitus contributions to Aurora have allowed the Company to continue operations and invest in oil and natural gas properties. Management anticipates that operating losses will continue until new wells are drilled, oil and natural gas prices improve, and or acquisitions are successfully completed and incremental production increases operating profit.
The Company has invested $529,974 and $1,569,514, respectively, in leases, and drilling and completion costs, for the nine months ended September 30, 2015 and 2014, respectively, and $0 and $3,397,122 in property acquisitions for the nine months ended September 30, 2015, and 2014, respectively.
 
The Company remains in active discussions with Navitus, and with other third parties relating to the capital infusion and longer term financing required to cover its existing and expected future deficit in cash flow from operating activities, reduce or pay its borrowing base deficiency (as defined below), pay its existing accounts payable and to fund its capital expenditures and property acquisitions planned for 2015 and 2016. Without additional outside investment from the sale of equity securities and/or debt financing, our capital expenditures and overhead expenses must be reduced to a level commensurate with available cash flows. The Company, through Aurora as borrower, entered a $25 million credit facility (the "Credit Agreement") with Texas Capital Bank, National Association on February 20, 2014. See Note 6 “Revolving Credit Agreement”. As of September 30, 2015 the Company has $730,000 in principal amount outstanding under the Credit Agreement. The accompanying consolidated financial statements are prepared as if the Company will continue as a going concern.

On April 13, 2015, the Company received the annual Borrowing Base Adjustment called for under the terms of the Revolving 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 in June 2015.
On May 13, 2015, Aurora informed the Lender it would not make the required $300,000 payment but was submitting its 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. As of June 3, 2015, the Company paid the aforementioned June monthly principal reduction of $10,000.

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 payment, as well as a forbearance document fee and Lender's legal expenses, all as required by the terms of the Forbearance Agreement, and the Forbearance Agreement went into effect for the $260,000 remaining borrowing base deficiency payment. Upon expiration of the Forbearance Agreement on August 31, 2015, the Company was required to make a $260,000 borrowing base deficiency payment to the Lender. On August 31, 2015, the Forbearance Agreement expired 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 principal payment to the lender on October 14, 2015 as part of that plan. Although the Company is in default of the Credit Agreement and related agreements,

11



the Company’s lender continues to cooperate with the Company in working out a payment plan and has not advised the Company of any additional actions it plans to take. See Note 11 - Subsequent Events.



12



Note 2 - Acquisitions
Business Combination
As previously disclosed in the Company's Form 8-K filed on February 4, 2015, Victory entered into a letter of intent ("LOI") relating to a proposed business combination with Lucas Energy, Inc. ("Lucas"). The business combination was contingent on, among other things, the parties completing due diligence, including title due diligence, the mutual negotiation of definitive documents, regulatory approvals and the registration of the securities to be issued to the shareholders of the combined company resulting from the Combination (the “Combined Company”).
On February 26, 2015, Victory entered into (a) the Pre-Merger Collaboration Agreement (the “Collaboration Agreement”) by and among Victory, Lucas, Navitus and AEP Assets, LLC, a wholly-owned subsidiary of Aurora (“AEP”); and (b) the Pre-Merger Loan and Funding Agreement (the “Loan Agreement”) between Victory and Lucas. Subsequently the parties entered into Amendment No. 1 to the Pre-Merger Collaboration Agreement on March 3, 2015 , which amendments affected thereby are included in the discussion of the Collaboration Agreement below.
On March 2, 2015, 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, pursuant to the Pre-Merger Collaboration Agreement 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 any other 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 0.5% per annum, with accrued interest payable in one lump sum on maturity. The maturity date of the Draw Note was February 26, 2016. A total of $600,000 was paid to Lucas through May 11, 2015, under the Draw Note.
On May 11, 2015, the Company terminated the LOI pursuant to its terms, which permitted either the Company or Lucas to terminate the LOI by written notification to the other party. The Company also notified Lucas pursuant to the Loan Agreement, as well as the related draw note would not extend any further credit to Lucas under the Loan Agreement. Merger and merger termination related direct costs total $1,326,850 and are included in general and administrative expenses for the nine months ended September 30, 2015.

On June 24, 2015, 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 June 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

Pursuant to the 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. Lucas acknowledged the principal amount of $600,000 previously advanced to Lucas by the Company pursuant to the terms of the Loan Agreement and agreed that the Company has no further obligations to advance any additional funds to Lucas pursuant to the terms of the Loan Agreement. Pursuant to the terms of the Lucas Settlement Agreement, Lucas agreed to issue 1,101,729 shares (44,069 post-split declared by Lucas as of July 15, 2015) shares of its common stock (the “Settlement Shares”) to the Company in full consideration of the $600,000 owed under the Loan Agreement. The Settlement Shares and an assignment of the Additional Penn Virginia Property was held in escrow pending the payment by the Company of amounts owed to Rogers under the Rogers Settlement (as described below). The Company has charged the $600,000 to general and administrative expenses as a cost of the merger termination.

Rogers Settlement Agreement

Pursuant to the Rogers Settlement Agreement, 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,

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2015, $253,750, 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 $253,750 ia made by the Company to the Rogers.

Amendment to Rogers Settlement Agreement

As of July 16, 2015, the Company entered into an Amendment (the “Rogers Amendment”). Pursuant to the Rogers Amendment, the Company and Rogers agreed that the amount to be paid by the Company to Rogers under the Rogers Settlement Agreement is $258,125, instead of $253,750. The Amendment further specified that if the Company failed to make the payment of $258,125 on or before July 15, 2015, the Company would be 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 $22,500. As of the date of this Quarterly Report on Form 10-Q, the Company has not made any payments to Rogers pursuant to the Rogers Settlement Agreement.

As described above, Rogers’ legal counsel held the assignment to the Company of Lucas Energy, Inc.’s rights additional Penn Virginia Property and the Settlement Shares in escrow pending the Company’s payment of all amounts due under the Rogers Settlement Agreement. The Company failed to make the required payment to Roger’s by August 27, 2015, and has still not made all the required payments. As a result, the additional Penn Virginia Property was returned to Lucas Energy, Inc. on or about June 24, 2015. The full amount due under the Roger’s obligation including accrued interest at September 30, 2015 totals $288,559.

Earthstone Settlement Agreement

Pursuant to the terms of the Earthstone Settlement Agreement, the Company assigned to Earthstone certain oil and gas interests in the wells which were previously transferred to the Company by Lucas in February 2015. The Company and Earthstone also agreed to release each other from any and all claims, demands and causes of action which either party had against the other prior to the effective date of the Earthstone Settlement Agreement, whether known or unknown, except in connection with the breach, enforcement or interpretation of the Earthstone Settlement Agreement. Lucas and Earthstone similarly agreed to release each other from such claims pursuant to the terms of the Earthstone Settlement Agreement. The Company has charged the $195,928 to general and administrative expenses as a cost of the merger termination.



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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,
2015
 
December 31, 2014
Oil and natural gas properties
$
3,578,864

 
$
2,838,573

Less: accumulated depletion
(2,036,467
)
 
(1,942,380
)
Oil and natural gas properties, net
$
1,542,397

 
$
896,193

 
Depletion, depreciation, accretion, and amortization expense for the three months ended September 30, 2015 and 2014 was $84,423 and $81,952, respectively, and for the nine months ended September 30, 2015 and 2014 was $335,437 and $252,024, respectively. During the nine months ended September 30, 2015 and 2014, the Company recorded impairment losses of $309,539 and $0, respectively. 

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, 2015 and the twelve months ended December 31, 2014.
 
 
September 30,
2015
 
December 31, 2014
Asset retirement obligation at beginning of period
$
44,214

 
$
51,954

Liabilities incurred on properties acquired and developed
2,505

 
3,721

Revisions to previous estimates

 
(14,821
)
Liabilities on properties sold or settled
(3,721
)
 

Accretion expense
4,593

 
3,360

Asset retirement obligation at end of period
$
47,591

 
$
44,214


Note 5 – Navitus Partnership Agreement

Under terms of the Second Amended Partnership Agreement of Aurora, Navitus earns a net profits interest respective to its 50% partnership interest, and earns rights to 50% of the proceeds of asset sales. Any distributions of the net profits or proceeds from the sale of assets to partners are at the discretion of Victory, as managing partner, together with 100% of the partnership interests. The accumulated net deficits of Navitus, along with historical contributions, net of distributions, are reported as non-controlling interests in the equity section of the condensed consolidated financial statements.

Under the terms of Aurora’s Seconded Amended Partnership Agreement, Navitus Partners, LLC, admitted under the Navitus Private Placement Memorandum (the "Navitus PPM"), earns a preferred return distribution of 10% based upon capital contributions to Aurora used by Victory to acquire or develop oil and gas prospects or related assets on behalf of Aurora. The preferred return distribution is in addition to and does not reduce any net profits interest. Since August 23, 2012, preferred distributions rights total $1,132,073 ($25,942 attributable to 2012, $232,373 attributable to 2013, $401,080 attributable to 2014, $137,361 attributable to the three months ended March 31, 2015, $163,959 attributable to the three months ended June 30, 2015, and 171,358 attributable to the three months ended September 30, 2015). Victory, as managing partner, may, in its sole discretion, choose to distribute all or a portion of the preferred returns, or, apply these funds to other partnership purposes.
 
Navitus Partners, LLC, a partner in Navitus, also receives warrants for Victory’s common stock, allocated 50,000 warrants for every unit ($50,000/unit) purchased under the Navitus PPM (equivalent of one (1) warrant for every $1.00 invested), exercisable under the terms of Aurora’s Second Amended Partnership Agreement and the Navitus PPM. Since August 23, 2012, $7,042,601 of capital contributions have resulted in issuance of 7,042,601 common stock warrants (1,100,000 in 2012, 2,191,601 in 2013, 1,140,000 in 2014, and 1,925,000 during the nine months ended September 30, 2015).

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Note 6 – Revolving Credit Agreement
 
On February 20, 2014, Aurora, as borrower, entered 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 June 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 June 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 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 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. At December 31, 2014, Aurora's Current Ratio was 0.10 to 1 and it was therefore not in compliance with the aforementioned Current Ratio covenant requiring a ratio of current assets to current liabilities of not less than 1 to 1. As of December 31, 2014, the $800,000 outstanding balance of the Credit Agreement was classified as a current liability in accordance with GAAP.

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 on June 2015 until the Lender’s next periodic borrowing base redetermination. The Company has 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.

As of June 30, 2015, the Company was out of compliance with the Current Ratio, and out of compliance with the EBITDAX to Cash Interest Ratio due to its reduced revenue streams from price and production declines and continued high general and administrative expenses for the quarter ended June 30, 2015.

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 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.

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Although the Company is in technical default of the Credit Agreement and related agreements, the Company’s lender continues to cooperate with the Company in working out a payment plan and has not advised the Company of any additional actions it plans to take.

Amortization of debt financing costs and interest expense on this debt for the nine months ended September 30, 2015 and 2014 was $30,617 and $24,380, respectively.

Note 7 - Rogers Settlement Obligation

Pursuant to the aforementioned merger termination, the Company had recorded a Promissory Note in the amount of $250,000 payable to Louise H. Rogers, Lucas’ senior lender in conjunction with the Pre Merger Collaboration Agreement, which accrues interest at the rate of 18% per annum. On May 11, 2015, the Company terminated the LOI with Lucas, pursuant to its terms, which permitted either the Company or Lucas to terminate the LOI by written notification to the other party. The Promissory Note was due and payable prior to August 17, 2015 in accordance with the Pre Merger Collaboration Agreement. In connection with the issuance of the Promissory Note, Louise H. Rogers had released the Well Rights from its security interest in order to accommodate the transactions contemplated by the Collaboration Agreement and Loan Agreement as of February 27, 2015. In connection to this note $250,000 has been charged to general and administrative expense as a cost of the terminated merger transaction through June 30, 2015 the interest was accrued at $125 per day for a total of $6,250. The September 30, 2015 balance of $290,433 is included in the Company’s Accrued Expenses in the June 30, 2015 Consolidated Financial Statements.

As of July 16, 2015, Victory entered into the Rogers Amendment. Pursuant to the Rogers Amendment, the Company and Rogers agreed to terminate the Promissory Noe and re-establish the amount to be paid by the Company as an obligation to Rogers under the Rogers Settlement Agreement is $258,125, instead of $253,750. The Rogers Amendment further specified that if the Company failed to make the obligation payment of $258,125 on or before July 15, 2015, the Company would be 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 $22,500. This amount was included in the Company’s accrued expenses as of September 30, 2015. As of the date of this Quarterly Report on Form 10-Q, the Company has not made any payments to Rogers pursuant to the Rogers Settlement Agreement.

As described above, Rogers’ legal counsel held the assignment to the Company of Lucas's rights to additional Penn Virginia Property and the Settlement Shares in escrow pending the Company’s payment of all amounts due under the Rogers Settlement Agreement. The Company failed to make the required payment to Roger’s by August 27, 2015, and has still not made all the required payments. As a result, the additional Penn Virginia Property was returned to Lucas Energy, Inc. The full amount due under the Roger’s obligation including accrued interest at September 30, 2015 totals $288,559.

Note 8 – Related Party Transactions
 
The Company has a combined receivable from Navitus and Blackacre Resources, LLC (an investment firm in which two members of the Company's board of directors are members of management) of $129,284 and $124,367 as of September 30, 2015 and December 31, 2014, respectively. The Company also uses legal services of one of its members of its Board of Directors in the ordinary course of the Company’s business. Accrued liabilities to affiliates as of September 30, 2015 and December 31, 2014 were $679,111 and $477,934, respectively. In accordance with the Second Amended Partnership Agreement, the Company receives a 2% management fee on gross receipts of Aurora. The management fee totaled $3,053 and $5,578 for the three and nine months ended September 30, 2015, and $11,594 and $92,362 for the three and nine months ended September 30, 2014, respectively.

Note 9 – Shareholders’ Equity
 
Common stock
 
The Company estimates the fair value of employee stock options and warrants granted using the Black-Scholes Option Pricing Model. Key assumptions used to estimate the fair value of warrants and stock options include the exercise price of the award, the fair value of the Company’s common stock on the date of grant, the expected warrant or option term, the risk free interest rate at the date of grant, the expected volatility and the expected annual dividend yield on the Company’s common stock. 

During the three months ended September 30, 2015 and in consideration of capital contributions by Aurora of $436,000 pursuant to the capital contribution agreement with Aurora, the Company issued 436,000 warrants to Navitus with an exercise price ranging from $0.25 - $0.35.


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The warrants vest immediately and the Company valued the common stock warrants using the Black Scholes Option Pricing Model for the three and nine months ended September 30, 2015 at $68,507 and $492,487, respectively.

During the nine months ended September 30, 2015, the Company issued 600,000 shares of stock options, which are vesting over a period of 36 months, and 1,305,000 shares of common stock to the board of directors for their services which are vested immediately.

Note 10 - 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.

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 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. On March 30, 2015 Victory filed a Motion for Rehearing in this case. On May 1, 2015 the Supreme Court sent a letter asking for Oz to file a response to Victory’s motion by May 18, 2015. Oz sought an extension of time to file their response, which was unopposed by Victory. The Supreme Court allowed the extension and Oz filed their Response to Motion for Rehearing on June 11, 2015. On June 17, 2015 Victory filed a Motion for Leave to file Reply in Support of Motion for Rehearing and filed said Reply on June 19, 2015. Oz then filed a Surreply to Petitioner’s Reply to Response to Motion for Rehearing on June 25, 2015. The Supreme Court has not taken any action at this time.

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. The lawsuit seeks to recover $200,000 from Crooked Oaks, LLC in addition to attorney’s fees and all costs of court.

On August 5, 2015 Victory received Notice from the District Court that this case was set on the Dismissal Docket for want of prosecution. Victory filed a Motion to Retain and the case is back on the docket. Pursuant to the local rules of Travis County, Texas, this case will be sent to mediation. If no agreement is reached at mediation, then the case will be put on the trial docket.

Cause No. 50198; Trilogy Operating, Inc. v. Aurora Energy Partners; In the 118th District Court of Howard County, Texas.

This lawsuit was filed on January 9, 2015. This lawsuit alleges causes of action for declaratory judgment, breach of contract, and suit to quiet title regarding the drilling and completion of four wells. On or about February 12, 2015, the parties met at an informal settlement conference. At the adjournment of the meeting, Trilogy was to provide Aurora with a detailed accounting before proceeding forward. The accounting provided by Trilogy was not helpful and Aurora has asked for an audit under the terms set

18



out in the Joint Operating Agreement, which Trilogy denied. On September 29, 2015 Trilogy amended its petition and now is seeking a declaratory judgment and assignments covering the four wells it has forfeited Aurora’s interest in. Trilogy has also filed a Motion for Summary Judgment that is set for hearing November 4, 2015. Depositions were just taken of Trilogy’s accountant and Aurora is preparing to file a Plea in Abatement, an Amended Answer and a Counter-Claim in this suit. Discovery is ongoing in this case and no trial date has been set at this time.
    
Cause No. 2015-05280; TELA Garwood Limited, LP. v. Aurora Energy Partners and Victory Energy Corporation; In the 164th District Court of Harris County, Texas.

This lawsuit was filed on January 30, 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 million. A second closing was to take place in September of 2014, however several title defect were found to exist. The title defects could not be cured and TELA would not agree to a purchase price reduction which ultimately lead to TELA terminating the second closing.

Aurora and Victory have filed an answer in this case. On March 4, 2015, TELA supplemented their petition adding all of the Victory board members to this lawsuit, however not everyone has been served. On April 30, 2015, Aurora and Victory filed a counterclaim against TELA alleging breach of contract, breach of warranty, fraud, fraud in the inception, negligent misrepresentation, and tortious interference with contract and business relationship. An answer, special exceptions and request for disclosure was filed on May 8, 2015 on behalf of the board members.

Discovery is ongoing in this case and no trial date has been set.

Note 11 - Subsequent Events

During the period of October 1, 2015 through October 29, 2015, additional capital contributions from noncontrolling interest of $225,000 were received. This resulted in the issuance of an additional 225,000 common stock warrants. On October 14, 2015, the Company made an additional principal payment of $50,000 towards the remaining credit facility balance.

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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, 2014 ("2014 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 discussed in “Cautionary Notice Regarding Forward Looking Statements and “Risk Factors” in this Quarterly Report on Form 10-Q and in our 2014 Form 10-K 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

Our Relationship with Aurora Energy Partners

Victory Energy Corporation is the managing partner of Aurora Energy Partners, a Texas general partnership (“Aurora”), and holds a 50% partnership interest in Aurora. Aurora is a consolidated subsidiary with Victory Energy Corporation for financial statement purposes. The Second Amended Partnership Agreement of Aurora ("Aurora Partnership Agreement") gives Victory Energy Corporation control of Aurora. Article XI of the Aurora Partnership Agreement cannot be modified unless there is a 100% vote of the partners, therefore Victory Energy Corporation cannot be removed as a managing member of Aurora regardless of the partnership interest held by the partners, and thus consolidation is appropriate for all reporting periods. Currently, Victory Energy Corporation conducts all of its oil and natural gas operations through, and holds some of its oil and natural gas assets through, Aurora, which owns record title to all of the oil and natural gas properties, wells and reserves referred to in this Quarterly Report on Form 10-Q. Through its partnership interest in Aurora, Victory Energy Corporation is the beneficial owner of 50% of such oil and gas properties, wells and reserves held of record by Aurora. 

Operational Overview and Strategy

The Company is an independent, growth-oriented oil and gas exploration and production company based in Austin, Texas. The Company is focused on the acquisition and development of stacked multi-pay resource play opportunities in Texas and New Mexico, as well as the Eagle Ford Shale area of Texas, that offer predictable outcomes and long-lived reserve characteristics.

Current Company assets include interests in proven formations such as the Spraberry, Wolfcamp, Wolfberry, Mississippian, Cline Fusselman and Eagle Ford formations. The Company’s objective is to create long-term shareholder value by increasing oil and natural gas reserves, improving financial returns (higher production volumes and lower costs), and managing the capital on its balance sheet. The Company is geographically focused onshore, with a primary focus in the Permian Basin of Texas and southeast New Mexico, with recent additions in the Eagle Ford Shale. The Company leverages both internal capabilities and strategic industry relationships to acquire working interest positions in low-to-moderate risk oil and natural gas prospects. Its focus is on oil or liquid-rich gas projects with longer-life reserves that offer competitive finding and development (F&D) costs.

At September 30, 2015, the Company held a working interest in 29 gross wells and an overriding royalty interest in seven gross wells, all located in the States of Texas and New Mexico. During the nine months ended September 30, 2015, the Company participated in the completion of 5 (gross) and 0.10 (net) wells, respectively. All wells were successfully completed.

On July 27, 2015, the Company received its consolidated third-party reserve study prepared by the independent reserve engineering firm historically utilized by the Company. The report was prepared on a basis consistent the Company’s January 1, 2015 study using the same SEC pricing methodology and rules, but represents July 1, 2015 values. This reserve report includes a 223% increase in net Proved Developed Producing crude oil reserves to 44.08 thousand barrels. In addition, the reserve report includes an increase in the undiscounted cash flow value of $556.5 thousand or 25.8%, and an increase in the present value of discounted at 10% cash flows (PV10) of $486.4 thousand or 38.7%. This additional resource value is directly attributable to the five Eagle Ford Penn Virginia operated wells noted above.

The July 1, 2015 reserve report is based upon oil and gas prices which are 25% and 22% lower, respectively, than those in the January 1, 2015 report and contributed to the Company’s significant impairment charge at June 30, 2015. The September 30, 2015, analogous prices have declined 12% and 6% for oil and natural gas respectively. The Company’s July 1, 2015 reserve study undiscounted cash flows equaled approximately $2.8 million. This report estimated the September 30 2015, undiscounted

20



cash flow would approximate $2.6 million without any change in pricing. Building into the effect of the noted pricing declines since July 1, 205, we estimate the Company undiscounted cash flows would be approximately $2.2 million based upon an average 20% overall value decline. The Company continues to monitor oil and gas prices but has determined that no material additional impairment of its oil and gas properties is required under GAAP as of September 30, 2015. With a continued decline in oil and gas prices the Company could incur additional impairment charges in the future.

Business Combination

As previously disclosed in the Company's Form 8-K filed on February 4, 2015, Victory entered into a letter of intent ("LOI") relating to a proposed business combination with Lucas Energy, Inc. ("Lucas"). The business combination was contingent on, among other things, the parties completing due diligence, including title due diligence, the mutual negotiation of definitive documents, regulatory approvals and the registration of the securities to be issued to the shareholders of the combined company resulting from the Combination (the “Combined Company”).
On February 26, 2015, Victory entered into (a) the Pre-Merger Collaboration Agreement (the “Collaboration Agreement”) by and among Victory, Lucas, Navitus and AEP Assets, LLC, a wholly-owned subsidiary of Aurora (“AEP”); and (b) the Pre-Merger Loan and Funding Agreement (the “Loan Agreement”) between Victory and Lucas. Subsequently the parties entered into Amendment No. 1 to the Pre-Merger Collaboration Agreement on March 3, 2015 , which amendments affected thereby are included in the discussion of the Collaboration Agreement below.
On March 2, 2015, 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, pursuant to the Pre-Merger Collaboration Agreement 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 any other 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 0.5% per annum, with accrued interest payable in one lump sum on maturity. The maturity date of the Draw Note was February 26, 2016. A total of $600,000 was paid to Lucas through May 11, 2015, under the Draw Note.
On May 11, 2015, the Company terminated the LOI pursuant to its terms, which permitted either the Company or Lucas to terminate the LOI by written notification to the other party. The Company also notified Lucas pursuant to the Loan Agreement, as well as the related draw note would not extend any further credit to Lucas under the Loan Agreement. Merger and merger termination related direct costs total $1,326,850 and are included in general and administrative expenses for the nine months ended September 30, 2015.

On June 24, 2015, 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 June 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

Pursuant to the 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. Lucas acknowledged the principal amount of $600,000 previously advanced to Lucas by the Company pursuant to the terms of the Loan Agreement and agreed that the Company has no further obligations to advance any additional funds to Lucas pursuant to the terms of the Loan Agreement. Pursuant to the terms of the Lucas Settlement Agreement, Lucas agreed to issue 1,101,729 shares (44,069 post-split declared by Lucas as of July 15, 2015) shares of its common stock (the “Settlement Shares”) to the Company in full consideration of the $600,000 owed under the Loan Agreement. The Settlement Shares and an assignment of the Additional Penn Virginia Property was held in escrow pending the payment by the Company of amounts owed to Rogers under the Rogers Settlement (as described below). The Company has charged the $600,000 to general and administrative expenses as a cost of the merger termination.

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Rogers Settlement Agreement

Pursuant to the Rogers Settlement Agreement, 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, $253,750, 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 $253,750 ia made by the Company to the Rogers.

Amendment to Rogers Settlement Agreement

As of July 16, 2015, the Company entered into an Amendment (the “Rogers Amendment”). Pursuant to the Rogers Amendment, the Company and Rogers agreed that the amount to be paid by the Company to Rogers under the Rogers Settlement Agreement is $258,125, instead of $253,750. The Amendment further specified that if the Company failed to make the payment of $258,125 on or before July 15, 2015, the Company would be 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 $22,500. As of the date of this Quarterly Report on Form 10-Q, the Company has not made any payments to Rogers pursuant to the Rogers Settlement Agreement.

As described above, Rogers’ legal counsel held the assignment to the Company of Lucas Energy, Inc.’s rights additional Penn Virginia Property and the Settlement Shares in escrow pending the Company’s payment of all amounts due under the Rogers Settlement Agreement. The Company failed to make the required payment to Roger’s by August 27, 2015, and has still not made all the required payments. As a result, the additional Penn Virginia Property was returned to Lucas Energy, Inc. on or about June 24, 2015. The full amount due under the Roger’s obligation including accrued interest at September 30, 2015 totals $288,559.


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Going Concern

The accompanying condensed 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. 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.

As presented in the condensed consolidated financial statements, the Company is reporting a net losses, attributable to Victory Energy Corporation, of $882,609 and $622,795 for the three months ended September 30, 2015 and 2014, respectively, and net losses of $3,676,640 and $785,910 for the nine months ended September 30, 2015 and 2014, respectively.

Our total cash and cash equivalents were $112,966 at September 30, 2015. We have been, and anticipate that we will continue to be, limited in terms of our capital resources. We generally have not had enough cash or sources of capital to pay our accounts payable and expenses as they arise. We will be required to raise substantial additional capital to meet our existing payment obligations and to expand our operations.
Proceeds from Navitus contributions to Aurora have allowed the Company to continue operations and invest in oil and natural gas properties. Management anticipates that operating losses will continue until new wells are drilled, oil and natural gas prices improve, and or acquisitions are successfully completed and incremental production increases operating profit.
The Company has invested $529,974 and $1,569,514, respectively, in leases, and drilling and completion costs, for the nine months ended September 30, 2015 and 2014, respectively, and $0 and $3,397,122 in property acquisitions for the nine months ended September 30, 2015, and 2014, respectively.
 
The Company remains in active discussions with Navitus, and with other third parties relating to the capital infusion and longer term financing required to cover its existing and expected future deficit in cash flow from operating activities, reduce or pay its borrowing base deficiency (as defined below), pay its existing accounts payable and to fund its capital expenditures and property acquisitions planned for 2015 and 2016. Without additional outside investment from the sale of equity securities and/or debt financing, our capital expenditures and overhead expenses must be reduced to a level commensurate with available cash flows. The Company, through Aurora as borrower, entered a $25 million credit facility (the "Credit Agreement") with Texas Capital Bank, National Association on February 20, 2014. See Note 6 “Revolving Credit Agreement”. As of September 30, 2015 the Company has $730,000 in principal amount outstanding under the Credit Agreement. The accompanying consolidated financial statements are prepared as if the Company will continue as a going concern.

On April 13, 2015, the Company received the annual Borrowing Base Adjustment called for under the terms of the Revolving 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 in June 2015.
On May 13, 2015, Aurora informed the Lender it would not make the required $300,000 payment but was submitting its 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. As of June 3, 2015, the Company paid the aforementioned June monthly principal reduction of $10,000.

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 cove a portion of the deficiency payment, as well as a forbearance document fee and Lender's legal expenses, all as required by the terms of the Forbearance Agreement, and the Forbearance Agreement went into effect for the $260,000 remaining borrowing base deficiency payment. Upon expiration of the Forbearance Agreement on August 31, 2015, the Company was required to make a $260,000 borrowing base deficiency payment to the Lender. On August 31, 2015, the Forbearance Agreement expired 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 principal payment to the lender on October 14, 2015 as part of that plan. Although, the Company is in default of the Credit Agreement and related agreements, the Company’s lender continues to cooperate with the Company in working out a payment plan and has not advised the Company of any additional actions it plans to take. See Note 11 - Subsequent Events.


23



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 stated growth through acquisitions and development business plan, the Company has incurred additional costs associated with a business combination and termination of the same acquisition, during the nine months ended September 30, 2015.  Among other things, these additional general and administrative expenses include legal, and geological analysis costs associated with title examination of properties, contractual purchase and sale agreements and third party reservoir engineering and geologic assessments for reserve calculations.  Additionally, as part of the Company’s credit facility agreement, we also pay related legal expenses for property review and assessment.  All of these expenses help us protect the assets of the Company and secure bank funding.  These specific expenses are not quarterly recurring per se, however they will occur again when additional opportunities to increase reserves and future development opportunities present themselves.  These expenses were significant, but enabled these key business growth transactions to be prudently structured and completed. We estimate the acquisition related costs to be significant as we continue to grow the asset base.

We have incurred significant expenses in conjunction with the terminated business combination with Lucas. These expenses include general and administrative expenses related to the engagement of professional services, specifically legal, tax, accounting and consulting. Merger and merger termination related direct costs total approximately $1.3 million and included in general and administrative expense for the nine months ended September 30, 2015.

We have incurred significant costs to structure and manage our debt facility and will continue to incur such costs as our asset base allows prudent borrowing against our proved reserves. These costs can fluctuate as debt instruments are ended, modified and replaced with new creditor entities. Refer to note 6.


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We have incurred costs associated with investor, public relations and capital funding which are critical to operate and expand in the public company arena. Additionally, the Company engaged an investor relations and corporate communications firm to help improve investor communications, capital markets development and awareness, and transactional legal costs related to non recurring business transactions.

We have incurred director, employee, and some limited vendor stock based compensation, all non-cash in nature, as part of our key employee acquisition and retention plan. As we grow through acquisitions, we need to add new talent and incentivize our current key employees to stay with the Company in addition to maintaining critical service providers.  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 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 month and nine month periods ended September 30, 2015, compared to the three month and nine month periods ended September 30, 2014.

Overall BOE production increased 26% and 34% respectively, for the three and nine month periods ended September 30, 2015. The rise in BOE production is primarily associated with the rise in oil production, which increased by 61% and 80% respectively, for the three and nine month periods ended September 30, 2015. The increase is the result of the additional production from the Eagle Ford properties acquired by Victory in the first quarter of 2015.

 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2015
 
2014
 
Change
 
2015
 
2014
 
Change
Period Production
 
 
 
 
 
 
 
 
 
 
 
Oil (Bbl)
2,940
 
1,830
 
61
 %
 
9,950
 
5,530
 
80
 %
Gas (Mcf)
9,623
 
10,644
 
(10
)%
 
32,581
 
35,618
 
(9
)%
BOE
4,544
 
3,604
 
26
 %
 
15,380
 
11,466
 
34
 %
Daily Production
 
 
 
 
 
 
 
 
 
 
 
Oil (Bbl/d)
33
 
20
 
65
 %
 
37
 
20
 
85
 %
Gas (Mcf/d)
107
 
118
 
(9
)%
 
121
 
132
 
(8
)%
BOE/d
50
 
40
 
25
 %
 
57
 
42
 
36
 %

During the three and nine month period ended September 30, 2015 and 2014, the price per barrel realized by the Company decreased from $66.97 to $44.94 or 33%, and from $75.43 to $47.86 or 37%, respectively. Over the same period, the price per Mcf realized by the Company decreased from $4.79 to $2.11 or 56% , and from $5.32 to $2.28 or 57% respectively.

 
For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
2015
 
2014
 
Change
 
2015
 
2014
 
Change
Realized Prices
 
 
 
 
 
 
 
 
 
 
 
Oil ($/bbl)
$
44.94

 
$
66.97

 
(33
)%
 
$
47.86

 
$
75.43

 
(37
)%
Gas ($/Mcf)
2.11

 
4.79

 
(56
)%
 
2.28

 
5.32

 
(57
)%
Value per BOE
$
33.55

 
$
48.15

 
(30
)%
 
$
35.80

 
$
52.89

 
(32
)%

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, 2015 and 2014.


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For the Three Months Ended September 30,
 
For the Nine Months Ended September 30,
 
Oil
 
Gas
 
Total
 
Oil
 
Gas
 
Total
 
 
 
 
 
 
 
 
 
 
 
 
2014 Sales
$
122,549

 
$
50,978

 
$
173,527

 
$
417,100

 
$
189,386

 
$
606,486

Change due to Volumes
74,338

 
(4,890
)
 
69,448

 
333,411

 
(16,150
)
 
317,261

Change due to Prices
(64,768
)
 
(25,759
)
 
(90,527
)
 
(274,277
)
 
(98,823
)
 
(373,100
)
2015 Sales
$
132,119

 
$
20,329

 
$
152,448

 
$
476,234

 
$
74,413

 
$
550,647


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 increased $69,448 and $317,261 due to volumes in the three month and nine month periods ended September 30, 2015, respectively. The increases were primarily driven by a rise in oil production for both periods, which was due to the continued production from the Eagle Ford properties assigned to the Company during the first quarter of 2015.

Oil and gas sales decreased $90,527 and $373,100 due to prices in the three month and nine month periods ended September 30, 2015 respectively, as a result of significant prices decreases for all commodities.

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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, 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 the Company 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, 2015 compared to the Three Months Ended September 30, 2014
 
The condensed consolidated operating statements of our revenue, operating expenses, and net income for the three months ended September 30, 2015 as compared to the three months ended September 30, 2014 were as follows:
 
 
(Unaudited)
 
 
 
 
 
Three Months Ended September 30,
 
 
 
Percentage
 
2015
 
2014
 
Change
 
Change
OIL AND GAS REVENUES
$
152,448

 
$
173,537

 
$
(21,089
)
 
(12
)%
COSTS AND EXPENSES
 
 
 
 
 

 
 

Lease operating expense
37,279

 
42,154

 
(4,875
)
 
(12
)%
Production taxes
7,178

 
9,547

 
(2,369
)
 
(25
)%
Dry hole costs

 
576

 
(576
)
 
(100
)%
Exploration and abandonment costs
(5,611
)
 
27,641

 
(33,252
)
 
(120
)%
General and administrative expense
941,822

 
656,586

 
285,236

 
43
 %
Impairment
3,152

 

 
3,152

 
100
 %
Depletion, depreciation, and amortization
84,423

 
81,952

 
2,471

 
3
 %
Total expenses
1,068,243

 
818,456

 
249,787

 
 

LOSS FROM OPERATIONS
(915,795
)
 
(644,919
)
 
(270,876
)
 
 
OTHER INCOME AND EXPENSE
 
 
 

 
 

 
 

Gain on sale of oil and gas properties

 
507

 
(507
)
 
(100
)%
Management fee income
3,053

 
3,470

 
(417
)
 
(12
)%
Interest expense
(32,220
)
 
(18,631
)
 
(13,589
)
 
73
 %
Total net other income and expense
(29,167
)
 
(14,654
)
 
(14,513
)
 
 

NET INCOME (LOSS) BEFORE TAX BENEFIT
(944,962
)
 
(659,573
)
 
(285,389
)
 
 
TAX BENEFIT

 

 
 

 
 

NET INCOME (LOSS)
(944,962
)
 
(659,573
)
 
(285,389
)
 
 
Less: Net income (loss) attributable to non-controlling interest
(62,353
)
 
(36,788
)
 
(25,565
)
 
69
 %
NET INCOME (LOSS) ATTRIBUTABLE TO VICTORY ENERGY CORPORATION
$
(882,609
)
 
$
(622,785
)
 
$
(259,824
)
 
(42
)%

Revenues: Our revenues decreased $21,089 or 12% to $152,448 for the three months ended September 30, 2015 from $173,537 for the three months ended September 30, 2014. The decrease in revenues is primarily associated with the decline in oil and natural gas commodity prices received by the Company, off set by an increase in production volumes. Oil and gas sales increased $69,448 due to volumes and decreased $90,527 due to declines in commodity prices for the the respective periods.

Lease operating expense: Lease operating expenses decreased $4,875 to $37,279 or 12% from $42,154 for the three months ended September 30, 2015. The decline is primarily the result of a decrease in the total aggregate working interests held by the Company during September 30, 2015 and September 30, 2014, as well as lower operating costs of the new property portfolio in 2015.

Production taxes: Production taxes are charged at the well head on the value of production of oil and natural gas. Production taxes decreased $2,369 or 25% to $7,178 for the three months ended September 30, 2015 from $9,547 for the three months ended

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September 30, 2014. The decline in production taxes is associated with the decline in oil and natural gas commodity prices from 2014 to 2015.

Exploration expense: Exploration expense decreased $33,252 or 120% for the three months ended September 30, 2015 as compared to the three months ended September 30, 2014. The decrease in exploration expense is primarily the result of a decline in geological and geophysical (G&G) costs associated with the services related to acquisition and divestiture work.

General and administrative expense: General and administrative expenses increased $285,236 or 43% to $941,822 for the three months ended September 30, 2015 from $656,586 for the three months ended September 30, 2014. The increase is primarily due to merger and merger termination costs, and an increase of legal fees for ongoing litigation.

Impairment of assets: Asset impairments increased $3,152 or 100% for the three months ended September 30, 2015 compared to the three months ended June 30, 2014. This increase is the result of the Company’s impairment of oil and gas properties associated with costs related to a 2014 acquisition disputed well.

Depletion, depreciation and amortization: Depletion, depreciation and amortization increased $2,471 or 3% to $84,423 for the three months ended September 30, 2015 from $81,952 for the three months ended September 30, 2014. The increase is primarily due to higher oil and natural gas production volumes.

Gain on sale of oil and natural gas properties: The $507 decrease in the gain on sale of oil and natural gas properties is due to the sale of the Lightnin' property during the three months ended September 30, 2014. No properties were sold for the nine months ended September 30, 2015.

Management fee income: Management fee income decreased $417 or 12% to $3,053 for the three months ended September 30, 2015. Victory charges a 2% management fee to Navitus Energy Group, a 50% partner of Aurora on only gross revenues which are attributable to Aurora.

Interest expense: Interest expense increased $13,589 for the three months ended September 30, 2015 from $18,631 of interest income (net) for the three months ended September 30, 2014. This is primarily due to higher interest rates in effect for 2015.

Income taxes: There is no provision for income tax recorded for either the three months ended September 30, 2015 or for the three months ended September 30, 2014 due to the net operating loss carry forwards (“NOLs”) up through the period ending June 30, 2015. Accordingly, the Company has recorded a full valuation allowance against its net deferred tax assets. Our NOLs generally begin to expire in 2025.


28



Nine Months Ended September 30, 2015 compared to the Nine Months Ended September 30, 2014
 
 
(Unaudited)
 
 
 
 
 
Nine Months Ended September 30,
 
 
 
Percentage
Change
 
2015
 
2014
 
Change
 
Inc (Dec)
REVENUE
$
550,647

 
$
606,487

 
$
(55,840
)
 
(9
)%
COSTS AND EXPENSES
 
 
 

 
 
 
 
Lease operating expense
114,296

 
157,786

 
(43,490
)
 
(28
)%
Production Taxes
26,719

 
34,809

 
(8,090
)
 
(23
)%
Exploration and abandonment costs
(2,120
)
 
51,813

 
(53,933
)
 
(104
)%
General and administrative expense
3,657,016

 
2,120,214

 
1,536,802

 
72
 %
Impairment
309,539

 

 
309,539

 
100
 %
Depletion, depreciation and amortization
335,437

 
252,024

 
83,413

 
33
 %
Total expenses
4,440,887

 
2,617,222

 
1,823,665

 
 
LOSS FROM OPERATIONS
(3,890,240
)
 
(2,010,735
)
 
(1,879,505
)
 
 
OTHER INCOME AND EXPENSE
 
 
 
 
 
 
 
Gain on sale of oil and gas properties

 
2,160,099

 
(2,160,099
)
 
(100
)%
Management fee income
5,728

 
92,362

 
(86,634
)
 
(94
)%
Interest expense
(79,406
)
 
(49,639
)
 
(29,767
)
 
60
 %
Total net other income and expense
(73,678
)
 
2,202,822

 
(2,276,500
)
 
 
INCOME (LOSS) BEFORE TAX BENEFIT
(3,963,918
)
 
192,087

 
(4,156,005
)
 
 

TAX BENEFIT

 

 

 
 

NET INCOME (LOSS)
(3,963,918
)
 
192,087

 
(4,156,005
)
 
 

Less: Net income (loss) attributable to non-controlling interest
(224,925
)
 
1,014,785

 
1,239,710

 
(122
)%
NET LOSS ATTRIBUTABLE TO VICTORY ENERGY CORPORATION
$
(3,738,993
)
 
$
(822,698
)
 
$
(2,916,295
)
 
354
 %

Revenues: Our revenues decreased $55,840 or 9% to $550,647 for the nine months ended September 30, 2015 from $606,487 for the nine months ended September 30, 2014. The decrease in revenues is primarily associated with the decline in oil and natural gas commodity prices received by the Company for the respective periods, offset by an increase in production volumes.

Lease operating expense: Lease operating expenses decreased $43,490 to $114,296 or 28% for the nine months ended September 30, 2015 from $157,786 for the nine months ended September 30, 2014. The decline is primarily the result of a decrease in the total aggregate working interests held by the Company during September 30, 2015 and 2014, as well as lower operating costs of the new property portfolio in 2015.

Production taxes: Production taxes are charged at the well head on the value of production of oil and natural gas. Production taxes decreased $8,090 or 23% to $26,719 for the nine months ended September 30, 2015 from $34,809 for the nine months ended September 30, 2014. The decline in production taxes is primarily associated with the decline in oil prices from 2014 to 2015.

Exploration and abandonment expense: Exploration expense decreased $53,933 or 104% to $2,120 from $51,813 for the nine months ended September 30, 2015 compared to the nine months ended September 30, 2014. The decrease in exploration expense is primarily the result of a decline in geological and geophysical (G&G) costs associated with the services related to acquisition and divestiture work, as well as a credit for settled asset retirement obligation.

General and administrative expense: General and administrative expenses increased $1,536,802 or 72% to $3,657,016 for the nine months ended September 30, 2015 from $2,120,214 for the nine months ended September 30, 2014. The increase is primarily due to merger and merger termination costs and an increase of legal fees for ongoing litigation.

Impairment of assets: Asset impairments increased $309,539 or 100% for the nine months ended September 30, 2015 compared to the nine months ended September 30, 2014. This increase is the result of the Company’s impairment of oil and gas properties as the industry experiences more sustained lower oil and natural gas commodity prices.

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Depletion, depreciation and amortization: Depletion, depreciation and amortization increased $83,413 or 33% to $335,437 for the nine months ended September 30, 2015 from $252,024 for the nine months ended September 30, 2014. The increase is primarily due to higher oil and natural gas production volumes.

Gain on sale of oil and natural gas properties: The $2,160,099 decrease in the gain on sale of oil and natural gas properties is due to the sale of the Lightnin' property during the nine months ended September 30, 2014. No properties were sold for the nine months ended September 30, 2015.

Management fee income: Management fee income decreased $86,634 or 94% to $5,728 for the nine months ended September 30, 2015. Victory charges a 2% management fee to Navitus Energy Group, a 50% partner of Aurora, on gross revenues which are attributable to Aurora.

Interest expense: Amortization of debt financing costs and interest expense increased $29,767 for the nine months ended September 30, 2015 from $49,639 of interest income (net) for the nine months ended September 30, 2014. This is primarily due to higher interest rates in effect for 2015.

Income taxes: There is no provision for income tax recorded for either the nine months ended September 30, 2015 or for the nine months ended September 30, 2014 due to the net operating loss carry forwards (“NOLs”) up through the period ending September 30, 2015. 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, 2015 as compared to December 31, 2014, are as follows:
 
 
September 30,
2015
 
December 31,
2014
 
 
 
 
Cash
$
112,966

 
$
2,941

Total current assets
$
270,755

 
$
190,719

Total assets
$
1,894,488

 
$
1,203,713

Total current liabilities
$
4,019,410

 
$
2,632,043

Total liabilities
$
4,052,702

 
$
2,672,536

 
At September 30, 2015, the Company had a working capital deficit of $3,748,655 compared to a working capital deficit of $2,441,324 at December 31, 2014. Current liabilities increased to $4,019,410 at September 30, 2015 from $2,632,043 at December 31, 2014.

Net cash used in operating activities for the nine months ended September 30, 2015 was $(1,901,001) after the net loss of $(3,963,918) was decreased by $805,715 in non-cash charges and offset by $1,257,202 in changes to the other operating assets and liabilities. This compares to cash used in operating activities for the nine months ended September 30, 2014 of $172,983 after the net loss for that period of $851,671 was decreased by $1,582,835 in non-cash charges and $104,866 in changes to other operating assets and liabilities.
 
Net cash used in investing activities for the nine months ended September 30, 2015 was $529,974, all of which was used for acquisitions, leases, drilling, and related costs. This compares to $772,801 in drilling and acquisition costs offset by $2,491,888 for acquisition of oil and gas properties, $4,021,000 in proceeds for the sale of our Lightnin' properties, $3,710 for the purchases of furniture and fixtures, and $22,577 for farm out of leaseholds sold for the six months ended June 30, 2014.
 
Net cash provided by financing activities for nine months ended September 30, 2015 was $2,541,000 of which $2,611,000 was contributions from Navitus and offset by $70,000 in principal payments on debt financing. This compares to $1,140,000 of contributions from Navitus, $647,421 in distributions to Navitus, $122,469 in costs for debt financing, and $800,000 from bank financing for the six months ended September 30, 2014, which resulted in net cash provided by financing activities of $1,309,630.


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On March 17, 2015, Aurora entered into a Waiver of Event of Default (the "Waiver Agreement") with the Lender. Under the terms of the Waiver Agreement, the Lender agreed to waive an event of default under the Loan Agreement for the fiscal quarters ended September 30, 2014 and December 31, 2014, subject to certain conditions which were met with the required time period allowed.

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 on June 2015 until the Lender’s next periodic borrowing base redetermination. The Company has made a principal payment in the amount of $10,000 principal 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. The Lender has received the additional reserve and related assignment information, and is currently evaluating the effect on the previously calculated Borrowing Base Deficiency.

The Company remained out of compliance with the current ratio covenant noted previously and has notified the Lender of such. As of September 30, 2015, the Company was out of compliance with the Current Ratio, and out of compliance with the EBITDAX to Cash Interest Ratio due to its reduced revenue streams from price and production declines and continued high general and administrative expenses.

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. This Forbearance Agreement will go into effect if no additional events of default have occurred with regard to the Credit Agreement, and upon the Company’s payment of $76,081 in payment for the Borrowing Base Deficiency, a forbearance document fee and Lender’s legal expenses. On August 26, 2015, the Company paid the Lender $76,081, and the aforementioned Forbearance Agreement went into effect for the$260,000 remaining borrowing base deficiency payment as August 31, 2015, at which time the Forbearance Agreement will terminate. 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 principal payment to the lender on October 14, 2015 as part of that plan. Although, the Company is in default of the Credit Agreement and related agreements, the Company’s lender continues to cooperate with the Company in working out a payment plan and has not advised the Company of any additional actions it plans to take.

As of the date of this Quarterly Report on Form 10-Q, we are, and anticipate that we will continue to be, limited in terms of our capital resources. We generally have not had enough cash or sources of capital to pay our accounts payable and expenses as they arise.
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, 2014 filed with the SEC on March 31, 2015.
 
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 Securities Exchange Act of 1934, as amended (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, the Company carried out an evaluation, with the participation of the Company’s management, including the Company’s Chief Executive Officer (“CEO”) and the Company’s Chief Financial Officer (‘CFO”),

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of the effectiveness of the Company’s disclosure controls and procedures (as defined under Rule 13a-15(e) under the Exchange Act) as of June 30, 2015. Based upon that evaluation, our management concluded that our control over financial reporting and related disclosure controls and procedures reflect a material weakness due to the size and nature of our Company.
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. Our management assessed the effectiveness of our internal control over financial reporting as of September 30, 2015. Based on this assessment, management identified the following material weakness that has caused management to conclude that, as of September 30, 2015, our disclosure controls and procedures, and our internal control over financial reporting, were not effective at the reasonable assurance level:

1.
We do not have 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 that resulted represented a material weakness. To address this material weakness, management performed additional analyzes 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.

2.
During 2014 and 2015, management implemented changes in internal controls for the timely review and approval by the Chief Financial Officer and Controller, of transaction details, in order to properly record them in accordance with GAAP.

To address this material weakness, management performed other procedures and additional analyses to ensure that the condensed consolidated financial statements included herein fairly present, in all material respects, our financial position, results of operations and cash flows for the periods presented. Accordingly, we believe that the condensed consolidated financial statements included in this report fairly present, in all material respects, our financial condition, results of operations and cash flows for the periods presented.
Changes in Internal Controls
The Company continued making changes during the period covered by this report, but these changes have not been tested and cannot be relied upon at this time.  These changes have included document version control of the filing document, supervisor review of all accounting entries to recording operator JIB invoices, and new operational accounting variance reports to analyze results of operations. Management plans to continue to put in place changes which will be designed to improve the internal controls over financial reporting during the remainder of 2015.  However, during the period covered by this report, there have been no changes in the Company’s internal controls over financial reporting that had a material effect, or that are reasonably likely to materially affect, on the Company’s internal controls over financial reporting.


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Part IIOther Information
 
Item 1. Legal Proceedings
 
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, 2014.
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, 2015, we had $112,966 of cash, current assets of $270,755, current liabilities of $4,019,410 and a working capital deficit of $3,748,655. Our current liabilities include $2,989,497 of accounts payable and accrued liabilities, some of which are past due, and $256,250 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 receivable. 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, 2015:

During the nine months ended September 30, 2015 we issued warrants to purchase shares of common stock at exercise prices ranging from $0.18 to $0.34 to Navitus in consideration of capital contributions to Aurora of $2,175,000 pursuant to the Company’s capital contribution agreement with Aurora.  The Company issued these warrants from January 1, 2015 through June 30, 2015.
 
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.
 
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.

33



Item 6. Exhibits
 
(a) Exhibits
 
 
 
 
31.1 **
 
Certification of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.**
 
 
 
31.2 **
 
Certification of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.**
 
 
 
32.1 **
 
Certification of Chief Executive Officer Pursuant to 18 U.S.C. Section 1350.**
 
 
 
32.2 **
 
Certification of Chief Financial Officer Pursuant to 18 U.S.C. Section 1350.**
 
 
 
101.INS*
 
XBRL Instance Document
 
 
 
101.SCH*
 
XBRL Taxonomy Extension Schema Document
 
 
 
101.CAL*
 
XBRL Taxonomy Extension Calculation Linkbase Document
 
 
 
101.DEF*
 
XBRL Taxonomy Extension Definition Linkbase Document
 
 
 
101.LAB*
 
XBRL Taxonomy Extension Label Linkbase Document
 
 
 
101.PRE*
 
XBRL Taxonomy Extension Presentation Linkbase Document
_____________
* 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.

34



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:
October 29, 2015
By:
/s/ Kenneth Hill
 
 
 
 
Kenneth Hill
 
 
 
 
Chief Executive Officer and Director
 
 
 
 
 
 
Date:
October 29, 2015
By:
/s/ Fred J. Smith, Jr.
 
 
 
 
Fred J. Smith, Jr.
 
 
 
 
Chief Financial Officer
 


35