10-Q 1 evolutionpetroleum2015q110-q.htm 10-Q
Table of Contents
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
ý QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended September 30, 2014
o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from to
Commission File Number 001-32942
EVOLUTION PETROLEUM CORPORATION
(Exact name of registrant as specified in its charter)

Nevada |  | 41-1781991
(State or other jurisdiction of incorporation or organization) |  | (IRS Employer Identification No.)

2500 CityWest Blvd., Suite 1300, Houston, Texas 77042
(Address of principal executive offices and zip code)
(713) 935-0122
(Registrant’s telephone number, including area code)
Not Applicable
(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 Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes: 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 the definition of “large accelerated filer”, “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer o |  | Accelerated filer x
Non-accelerated filer o |  | Smaller reporting company o

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
The number of shares outstanding of the registrant’s common stock, par value $0.001, as of November 4, 2014, was 32,797,644.

EVOLUTION PETROLEUM CORPORATION AND SUBSIDIARIES
TABLE OF CONTENTS

|  | Page
PART I. FINANCIAL INFORMATION | 2
ITEM 1. | UNAUDITED CONSOLIDATED CONDENSED FINANCIAL STATEMENTS | 2
| Unaudited Consolidated Condensed Balance Sheets as of September 30, 2014 and June 30, 2014 | 2
| Unaudited Consolidated Condensed Statements of Operations for the three months ended September 30, 2014 and 2013 | 3
| Unaudited Consolidated Condensed Statements of Cash Flows for the three months ended September 30, 2014 and 2013 | 4
| Unaudited Consolidated Condensed Statement of Stockholders’ Equity for the three months ended September 30, 2014 | 5
| Notes to Unaudited Consolidated Condensed Financial Statements | 6
ITEM 2. | MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS | 14
ITEM 3. | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK | 19
ITEM 4. | CONTROLS AND PROCEDURES | 19
PART II. OTHER INFORMATION | 20
ITEM 1. | LEGAL PROCEEDINGS | 20
ITEM 1A. | RISK FACTORS | 21
ITEM 2. | UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS | 21
ITEM 3. | DEFAULTS UPON SENIOR SECURITIES | 21
ITEM 4. | MINE SAFETY DISCLOSURES | 21
ITEM 5. | OTHER INFORMATION | 21
ITEM 6. | EXHIBITS | 22
SIGNATURES |  | 23

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PART I — FINANCIAL INFORMATION
ITEM 1. CONSOLIDATED CONDENSED FINANCIAL STATEMENTS
Evolution Petroleum Corporation and Subsidiaries
Consolidated Condensed Balance Sheets
(Unaudited)

| September 30, 2014 |  | June 30, 2014
Assets |  |  |  |  |
Current assets |  |  |  |  |
Cash and cash equivalents | $ | 21,368,144 |  |  | $ | 23,940,514 |
Receivables |  |  |  |  |
Oil and natural gas sales | 1,268,122 |  |  | 1,456,146 |
Other | 23,524 |  |  | 1,066 |
Deferred tax asset | 159,624 |  |  | 159,624 |
Prepaid expenses and other current assets | 632,706 |  |  | 747,453 |
Total current assets | 23,452,120 |  |  | 26,304,803 |
Oil and natural gas property and equipment, net (full-cost method of accounting) | 37,651,450 |  |  | 37,822,070 |
Other property and equipment, net | 444,942 |  |  | 424,827 |
Total property and equipment | 38,096,392 |  |  | 38,246,897 |
Other assets | 527,341 |  |  | 464,052 |
Total assets | $ | 62,075,853 |  |  | $ | 65,015,752 |
Liabilities and Stockholders’ Equity |  |  |  |  |
Current liabilities |  |  |  |  |
Accounts payable | $ | 611,547 |  |  | $ | 441,722 |
State and federal income taxes payable | 44,173 |  |  | — |
Accrued liabilities and other | 874,013 |  |  | 2,558,004 |
Total current liabilities | 1,529,733 |  |  | 2,999,726 |
Long term liabilities |  |  |  |  |
Deferred income taxes | 10,021,875 |  |  | 9,897,272 |
Asset retirement obligations | 209,028 |  |  | 205,512 |
Deferred rent | 31,434 |  |  | 35,720 |
Total liabilities | 11,792,070 |  |  | 13,138,230 |
Commitments and contingencies (Note 12) |  |  |  |  |
Stockholders’ equity |  |  |  |  |
Preferred stock, par value $0.001; 5,000,000 shares authorized:8.5% Series A Cumulative Preferred Stock, 1,000,000 shares authorized, 317,319 shares issued and outstanding at September 30, 2014 and June 30, 2014 with a liquidation preference of $7,932,975 ($25.00 per share) | 317 |  |  | 317 |
Common stock; par value $0.001; 100,000,000 shares authorized: issued and outstanding 32,797,743 shares and 32,615,646 as of September 30, 2014 and June 30, 2014, respectively | 32,797 |  |  | 32,615 |
Additional paid-in capital | 35,357,362 |  |  | 34,632,377 |
Retained earnings | 14,893,307 |  |  | 17,212,213 |
Total stockholders’ equity | 50,283,783 |  |  | 51,877,522 |
Total liabilities and stockholders’ equity | $ | 62,075,853 |  |  | $ | 65,015,752 |

See accompanying notes to consolidated condensed financial statements.
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Evolution Petroleum Corporation and Subsidiaries
Consolidated Condensed Statements of Operations
(Unaudited)

| Three Months Ended September 30,
| 2014 |  | 2013
Revenues |  |  |  |  |
Delhi field | $ | 3,868,602 |  |  | $ | 4,429,811 |
Artificial lift technology | 115,856 |  |  | 142,091 |
Other properties | 20,369 |  |  | 61,797 |
Total revenues | 4,004,827 |  |  | 4,633,699 |
Operating costs |  |  |  |  |
Production costs - artificial lift technology | 197,360 |  |  | 163,749 |
Production costs - other properties | 88,022 |  |  | 254,501 |
Depreciation, depletion and amortization | 369,350 |  |  | 309,673 |
Accretion of discount on asset retirement obligations | 4,636 |  |  | 12,928 |
General and administrative expenses * | 1,504,593 |  |  | 1,928,951 |
Total operating costs | 2,163,961 |  |  | 2,669,802 |
Income from operations | 1,840,866 |  |  | 1,963,897 |
Other |  |  |  |  |
Interest income | 12,763 |  |  | 7,703 |
Interest (expense) | (18,460 | ) |  | (16,513 | )
Net income before income taxes | 1,835,169 |  |  | 1,955,087 |
Income tax provision | 706,159 |  |  | 482,636 |
Net income attributable to the Company | $ | 1,129,010 |  |  | $ | 1,472,451 |
Dividends on preferred stock | 168,575 |  |  | 168,575 |
Net income available to common stockholders | $ | 960,435 |  |  | $ | 1,303,876 |
Earnings per common share |  |  |
Basic | $ | 0.03 |  |  | $ | 0.05 |
Diluted | $ | 0.03 |  |  | $ | 0.04 |
Weighted average number of common shares |  |  |  |  |
Basic | 32,682,401 |  |  | 28,607,320 |
Diluted | 32,826,250 |  |  | 32,211,265 |

* General and administrative expenses for the three months ended September 30, 2014 and 2013 included non-cash stock-based compensation expense of $243,337 and $373,438, respectively.
See accompanying notes to consolidated condensed financial statements.
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Evolution Petroleum Corporation and Subsidiaries
Consolidated Condensed Statements of Cash Flows
(Unaudited)

| Three Months Ended September 30,
| 2014 |  | 2013
Cash flows from operating activities |  |  |  |  |
Net income attributable to the Company | $ | 1,129,010 |  |  | $ | 1,472,451 |
Adjustments to reconcile net income to net cash provided by operating activities: |  |  |  |  |
Depreciation, depletion and amortization | 381,509 |  |  | 319,885 |
Stock-based compensation | 243,337 |  |  | 373,438 |
Accretion of discount on asset retirement obligations | 4,636 |  |  | 12,928 |
Settlements of asset retirement obligations | (226,008 | ) |  | — |
Deferred income taxes | 124,603 |  |  | 72,395 |
Deferred rent | (4,286 | ) |  | (4,286 | )
Changes in operating assets and liabilities: |  |  |  |  |
Receivables from oil and natural gas sales | 188,024 |  |  | 11,133 |
Receivables from income taxes and other | (22,458 | ) |  | 918 |
Due from joint interest partner | — |  |  | (14,614 | )
Prepaid expenses and other current assets | 114,747 |  |  | 53,948 |
Accounts payable and accrued expenses | (1,345,875 | ) |  | (1,146,080 | )
Income taxes payable | 44,173 |  |  | 404,677 |
Net cash provided by operating activities | 631,412 |  |  | 1,556,793 |
Cash flows from investing activities |  |  |  |  |
Proceeds from asset sales | — |  |  | 66,753 |
Capital expenditures for oil and natural gas properties | (1,136 | ) |  | (594,214 | )
Capital expenditures for other property and equipment | (156,798 | ) |  | — |
Other assets | (55,046 | ) |  | (1,913 | )
Net cash used in investing activities | (212,980 | ) |  | (529,374 | )
Cash flows from financing activities |  |  |  |  |
Cash dividends to preferred stockholders | (168,575 | ) |  | (168,575 | )
Cash dividends to common stockholders | (3,279,341 | ) |  | — |
Acquisitions of treasury stock | (55,452 | ) |  | (117,182 | )
Tax benefits related to stock-based compensation | 537,282 |  |  | — |
Recovery of short swing profits | — |  |  | 6,850 |
Deferred loan costs | (24,716 | ) |  | — |
Net cash used in financing activities | (2,990,802 | ) |  | (278,907 | )
Net increase (decrease) in cash and cash equivalents | (2,572,370 | ) |  | 748,512 |
Cash and cash equivalents, beginning of period | 23,940,514 |  |  | 24,928,585 |
Cash and cash equivalents, end of period | $ | 21,368,144 |  |  | $ | 25,677,097 |

Supplemental disclosures of cash flow information:

| Three Months Ended September 30,
| 2014 |  | 2013
Income taxes paid | $ | — |  |  | $ | — |
Non-cash transactions: |  |  |  |  |
Change in accounts payable used to acquire property and equipment | (31,806 | ) |  | (136,436 | )
Oil and natural gas property costs incurred through recognition of asset retirement obligations | — |  |  | 45,172 |

See accompanying notes to consolidated condensed financial statements.
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Evolution Petroleum Corporation and Subsidiaries
Consolidated Condensed Statement of Changes in Stockholders' Equity
For the Three Months Ended September 30, 2014
(Unaudited)

| Preferred |  | Common Stock |  |  |  |  |  |  |  |
| Additional Paid-in Capital |  | Retained Earnings |  | Treasury Stock |  | Total Stockholders' Equity
| Shares |  | Par Value |  | Shares |  | Par Value |
Balance, June 30, 2014 | 317,319 |  |  | $ | 317 |  |  | 32,615,646 |  |  | $ | 32,615 |  |  | $ | 34,632,377 |  |  | $ | 17,212,213 |  |  | $ | — |  |  | $ | 51,877,522 |
Issuance of restricted common stock | — |  |  | — |  |  | 187,726 |  |  | 188 |  |  | (188 | ) |  | — |  |  | — |  |  | — |
Acquisitions of treasury stock | — |  |  | — |  |  | (5,629 | ) |  | — |  |  | — |  |  | — |  |  | (55,452 | ) |  | (55,452 | )
Retirements of treasury stock | — |  |  | — |  |  | — |  |  | (6 | ) |  | (55,446 | ) |  | — |  |  | 55,452 |  |  | — |
Stock-based compensation | — |  |  | — |  |  | — |  |  | — |  |  | 243,337 |  |  | — |  |  | — |  |  | 243,337 |
Tax benefits related to stock-based compensation | — |  |  | — |  |  | — |  |  | — |  |  | 537,282 |  |  | — |  |  | — |  |  | 537,282 |
Net income | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | 1,129,010 |  |  | — |  |  | 1,129,010 |
Common stock cash dividends | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (3,279,341 | ) |  | — |  |  | (3,279,341 | )
Preferred stock cash dividends | — |  |  | — |  |  | — |  |  | — |  |  | — |  |  | (168,575 | ) |  | — |  |  | (168,575 | )
Balance, September 30, 2014 | 317,319 |  |  | $ | 317 |  |  | 32,797,743 |  |  | $ | 32,797 |  |  | $ | 35,357,362 |  |  | $ | 14,893,307 |  |  | $ | — |  |  | $ | 50,283,783 |

See accompanying notes to consolidated condensed financial statements.
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Evolution Petroleum Corporation And Consolidated Subsidiaries
Notes to Unaudited Consolidated Condensed Financial Statements
Note 1 — Organization and Basis of Preparation
Nature of Operations. Evolution Petroleum Corporation ("EPM") and its subsidiaries (the "Company", "we", "our" or
"us"), is an independent petroleum company headquartered in Houston, Texas and incorporated under the laws of the State of
Nevada. We are engaged primarily in the development of incremental oil and gas reserves within known oil and gas resources
for our shareholders and customers utilizing conventional and proprietary technology.
Interim Financial Statements. The accompanying unaudited consolidated condensed financial statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information and with the appropriate rules and regulations of the Securities and Exchange Commission (“SEC”). Accordingly, certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States have been condensed or omitted pursuant to such rules and regulations. All adjustments (consisting of normal recurring accruals) which are, in the opinion of management, necessary for a fair presentation of the financial position and results of operations for the interim periods presented have been included. The interim financial information and notes hereto should be read in conjunction with the Company’s 2014 Annual Report on Form 10-K for the fiscal year ended June 30, 2014, as filed with the SEC. The results of operations for interim periods are not necessarily indicative of results to be expected for a full fiscal year.
Principles of Consolidation and Reporting. Our consolidated financial statements include the accounts of EPM and its
wholly-owned subsidiaries. All significant intercompany transactions have been eliminated in consolidation. The consolidated
financial statements for the previous year include certain reclassifications that were made to conform to the current
presentation. Such reclassifications have no impact on previously reported net income or stockholders' equity.
Use of Estimates. The preparation of financial statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets and liabilities at the dates of the financial statements and the reported amounts of revenues and expenses during the reporting periods. Significant estimates include reserve quantities and estimated future cash flows associated with proved reserves, which significantly impact depletion expense and potential impairments of oil and natural gas properties, income taxes and the valuation of deferred tax assets, stock-based compensation and commitments and contingencies. We analyze our estimates based on historical experience and various other assumptions that we believe to be reasonable. While we believe that our estimates and assumptions used in preparation of the consolidated financial statements are appropriate, actual results could differ from those estimates.
Note 2 — Property and Equipment
As of September 30, 2014 and June 30, 2014, our oil and natural gas properties and other property and equipment consisted of the following:

| September 30, 2014 |  | June 30, 2014
Oil and natural gas properties |  |  |  |  |
Property costs subject to amortization | $ | 47,167,417 |  |  | $ | 47,166,282 |
Less: Accumulated depreciation, depletion, and amortization | (9,515,967 | ) |  | (9,344,212 | )
Oil and natural gas properties, net | $ | 37,651,450 |  |  | $ | 37,822,070 |
Other property and equipment |  |  |  |  |
Furniture, fixtures and office equipment, at cost | $ | 348,507 |  |  | $ | 343,178 |
Artificial lift technology equipment, at cost | 497,606 |  |  | 377,943 |
Less: Accumulated depreciation | (401,171 | ) |  | (296,294 | )
Other property and equipment, net | $ | 444,942 |  |  | $ | 424,827 |

During the quarter ended September 30, 2014, we incurred $119,663 of costs related to the installation of our artificial lift technology on wells for a third-party customer. Under the contract for these installations, we fund the majority of the
incremental equipment and installation costs and will receive 25% of the net profits from production, as defined, for as long as
the technology remains in the wells. We are depreciating these costs using a method and a life which approximates the relative timing and amounts of our expected net revenues from the wells. During the quarter ended September 30, 2014, we recorded
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Evolution Petroleum Corporation And Consolidated Subsidiaries
Notes to Unaudited Consolidated Condensed Financial Statements
additional depreciation of $76,515 to expense the unrecovered installation costs of artificial lift equipment which was removed from one well and reinstalled in another well of a third-party customer.
Note 3 — Accrued Liabilities and Other
As of September 30, 2014 and June 30, 2014 our other current liabilities consisted of the following:

| September 30, 2014 |  | June 30, 2014
Accrued incentive and other compensation | $ | 323,318 |  |  | $ | 1,358,653 |
Accrued restructuring charges | 175,307 |  |  | 530,412 |
Officer retirement costs | 116,289 |  |  | 288,258 |
Asset retirement obligations due within one year | 10,219 |  |  | 146,703 |
Accrued royalties | 77,376 |  |  | 89,179 |
Accrued franchise taxes | 113,027 |  |  | 87,575 |
Other accrued liabilities | 58,477 |  |  | 57,224 |
Accrued liabilities and other | $ | 874,013 |  |  | $ | 2,558,004 |

Note 4 — Restructuring
On November 1, 2013, we undertook an initiative to refocus our business to GARP® development that resulted in an
adjustment of our workforce with less emphasis on oil and gas operations and greater emphasis on sales and marketing. In exchange for severance and non-compete agreements with the terminated employees, we recorded a restructuring charge of approximately $1,332,186 representing $376,365 of stock-based compensation from the accelerated vesting of equity awards and $955,821 of severance compensation and benefits to be paid during the twelve months ended December 31, 2014. Our current estimate of the remaining accrued restructuring charges as of September 30, 2014 is as follows:

Type of Cost | Balance at December 31, 2013 |  | Payments |  | Adjustment to Cost |  | September 30, 2014
Salary continuation liability | $ | 615,721 |  |  | $ | (461,790 | ) |  | $ | — |  |  | $ | 153,931 |
Incentive compensation costs | 185,525 |  |  | (185,525 | ) |  | — |  |  | — |
Other benefit costs and employer taxes | 154,575 |  |  | (94,199 | ) |  | (39,000 | ) |  | 21,376 |
Accrued restructuring charges | $ | 955,821 |  |  | $ | (741,514 | ) |  | $ | (39,000 | ) |  | $ | 175,307 |

Note 5 — Asset Retirement Obligations
Our asset retirement obligations represent the estimated present value of the amount we will incur to plug, abandon and
remediate our producing properties at the end of their productive lives in accordance with applicable laws. The following is a
reconciliation of the beginning and ending asset retirement obligations for the three months ended September 30, 2014, and for the year ended June 30, 2014:

| September 30, 2014 |  | June 30, 2014
Asset retirement obligations — beginning of period | $ | 352,215 |  |  | $ | 615,551 |
Liabilities sold | — |  |  | (48,273 | )
Liabilities incurred | — |  |  | — |
Liabilities settled | (137,604 | ) |  | (323,665 | )
Accretion of discount | 4,636 |  |  | 41,626 |
Revision of previous estimates | — |  |  | 66,976 |
Less obligations due within one year | (10,219 | ) |  | (146,703 | )
Asset retirement obligations — end of period | $ | 209,028 |  |  | $ | 205,512 |

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Evolution Petroleum Corporation And Consolidated Subsidiaries
Notes to Unaudited Consolidated Condensed Financial Statements
Note 6— Stockholders’ Equity
Common Stock
Commencing in December 2013, the Board of Directors initiated a quarterly cash dividend on our common stock at a quarterly rate of $0.10 per share. During the three months ended September 30, 2014, we paid $3,279,341 of dividends to our common shareholders.
For the quarter ended September 30, 2014, the Board of Directors authorized the issuance of 144,468 shares of restricted common stock from the 2004 Stock Plan to all employees as a long-term incentive award. In addition, the Board authorized the issuance of 43,258 shares of restricted common stock to various employees for incentive compensation purposes. See Note 7 - Stock-Based Incentive Plan.
Series A Cumulative Perpetual Preferred Stock
At September 30, 2014, there were 317,319 shares of the Company’s 8.5% Series A Cumulative (perpetual) Preferred Stock outstanding. The Series A Cumulative Preferred Stock cannot be converted into our common stock and there are no sinking fund or redemption rights available to the holders thereof. Optional redemption can only be made by us on or after July 1, 2014 for the stated liquidation value of $25.00 per share plus accrued dividends. With respect to dividend rights and rights upon our liquidation, winding-up or dissolution, the Series A Preferred Stock ranks senior to our common shareholders, but subordinate to any of our existing and future debt. Dividends on the Series A Cumulative Preferred Stock accrue and accumulate at a fixed rate of 8.5% per annum on the $25.00 per share liquidation preference, payable monthly at $0.177083 per share, as, if and when declared by our Board of Directors through its Dividend Committee. We paid dividends of $168,575 and $168,575 to holders of our Series A Preferred Stock during the three months ended September 30, 2014 and 2013, respectively.
Expected Tax Treatment of Dividends
For the fiscal year ended June 30, 2014, cash dividends on preferred and common stock were treated for tax purposes as a return of capital to our shareholders. Based on our current projections we expect that the majority, if not all, of our cash dividends for the fiscal year ending June 30, 2015 will be treated as qualified dividend income and not as a return of capital. We will make a final determination regarding the tax treatment of dividends for the current fiscal year when we report this information to recipients.
Note 7 — Stock-Based Incentive Plan
We may grant option awards to purchase common stock (the "Stock Options"), restricted common stock awards
("Restricted Stock"), and unrestricted fully vested common stock, to employees, directors, and consultants of the Company
under the Evolution Petroleum Corporation Amended and Restated 2004 Stock Plan (the "Plan"). The Plan authorizes the
issuance of 6,500,000 shares of common stock and 568,269 shares remain available for grant as of September 30, 2014.
Stock Options
No Stock Options have been granted since August 2008 and all compensation costs attributable to Stock Options have been recognized in prior periods.
The following summary presents information regarding outstanding Stock Options as of September 30, 2014, and the changes during the fiscal year:

| Number of Stock Options and Incentive Warrants |  | Weighted Average Exercise Price |  | Aggregate Intrinsic Value (1) |  | Weighted Average Remaining Contractual Term (in years)
Stock Options outstanding at July 1, 2014 | 178,061 |  |  | $ | 2.08 |  |  |  |  |  |
Stock Options outstanding at September 30, 2014 | 178,061 |  |  | $ | 2.08 |  |  | $ | 1,264,907 |  |  | 1.5
Vested or expected to vest at September 30, 2014 | 178,061 |  |  | $ | 2.08 |  |  | $ | 1,264,907 |  |  | 1.5
Exercisable at September 30, 2014 | 178,061 |  |  | $ | 2.08 |  |  | $ | 1,264,907 |  |  | 1.5

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Evolution Petroleum Corporation And Consolidated Subsidiaries
Notes to Unaudited Consolidated Condensed Financial Statements
(1) Based upon the difference between the market price of our common stock on the last trading date of the period ($9.18 as of September 30, 2014) and the Stock Option exercise price of in-the-money Stock Options.
Restricted Stock and Contingent Restricted Stock
Prior to the quarter ended September 30, 2014 all restricted stock grants contained a four-year vesting period based solely on service. Restricted stock which vests based solely on service is valued at the fair market value on the date of grant and amortized over the service period.
During the three months ended September 30, 2014, the Company awarded long-term incentive grants of both restricted stock and contingent restricted stock. Such grants, which expire after four years if unvested, contain service-based, performance-based and market-based vesting provisions. The common shares underlying the restricted stock grants were issued on the date of grant, whereas the contingent restricted stock will be issued only upon the attainment of specified performance-based or market-based vesting provisions.
Performance-based grants vest upon the attainment of earnings, revenue and other operational goals and require that the recipient remain an employee of the Company upon vesting. The Company recognizes compensation expense for performance-based awards ratably over the expected vesting period when it is deemed probable, for accounting purposes, that the performance criteria will be achieved. The expected vesting period may be deemed to be shorter than the remainder of the four year term. As of September 30, 2014, the Company does not consider the vesting of these performance-based grants to be probable and no compensation expense has been recognized.
Market-based awards entitle employees to vest in a fixed number of shares when the three-year trailing total return on the Company’s common stock exceeds the corresponding total returns of various quartiles of companies comprising the SIG Exploration and Production Index (NASDAQ EPX) during defined measurement periods. The fair value and expected vesting period of these awards was determined using a Monte Carlo simulation based on the historical volatility of the Company's total return compared to the historical volatilities of the other companies in the index. Fair values for these market-based awards ranged from $4.26 to $8.40 with expected vesting periods of 3.30 to 2.55 years, based on the various quartiles of comparative market performance. Compensation expense for market-based awards is recognized over the expected vesting period using the straight-line method, so long as the award holder remains an employee of the Company. Total compensation expense is based on the fair value of the awards at the date of grant and is independent of vesting or expiration of the awards, except for termination of service.
The following table sets forth the Restricted Stock transactions for the three months ended September 30, 2014:

| Number of Restricted Shares |  | Weighted Average Grant-Date Fair Value |  | Unamortized Compensation Expense at September 30, 2014 (1) |  | Weighted Average Remaining Amortization Period (Years)
Unvested at July 1, 2014 | 140,067 |  |  | $ | 8.70 |  |  |  |  |
Service-based shares granted | 75,170 |  |  | 10.13 |  |  |  |  |
Performance-based shares granted | 76,642 |  |  | 10.05 |  |  |  |  |
Market-based shares granted | 35,914 |  |  | 7.59 |  |  |  |  |
Vested | (21,873 | ) |  | 6.86 |  |  |  |  |
Unvested at September 30, 2014 | 305,920 |  |  | $ | 9.39 |  |  | $ | 1,789,833 |  |  | 2.9

(1) Excludes $770,252 of potential future compensation expense for performance-based awards that are not probable.
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Notes to Unaudited Consolidated Condensed Financial Statements
The following table summarizes Contingent Restricted Stock activity:

| Number of Restricted Stock Units |  | Weighted Average Grant-Date Fair Value |  | Unamortized Compensation Expense at September 30, 2014 (1) |  | Weighted Average Remaining Amortization Period (Years)
Unvested at July 1, 2014 | — |  |  | $ | — |  |  |  |  |
Performance-based awards granted | 38,325 |  |  | 10.05 |  |  |  |  |
Market-based awards granted | 17,961 |  |  | 4.26 |  |  |  |  |
Unvested at September 30, 2014 | 56,286 |  |  | $ | 8.20 |  |  | $ | 74,502 |  |  | 3.2

(1) Excludes $385,166 of potential future compensation expense for performance-based awards that are not probable.
Stock-based compensation expense related to Restricted Stock and Contingent Restricted Stock grants for the three months ended September 30, 2014 and 2013 was $243,337 and $373,438, respectively.
Note 8 — Fair Value Measurement
Accounting guidelines for measuring fair value establish a three-level valuation hierarchy for disclosure of fair value measurements. The valuation hierarchy categorizes assets and liabilities measured at fair value into one of three different levels depending on the observability of the inputs employed in the measurement.
The three levels are defined as follows:
Level 1 — Observable inputs such as quoted prices in active markets at the measurement date for identical, unrestricted assets or liabilities.
Level 2 — Other inputs that are observable directly or indirectly such as quoted prices in markets that are not active, or inputs which are observable, either directly or indirectly, for substantially the full term of the asset or liability.
Level 3 — Unobservable inputs for which there is little or no market data and which the Company makes its own assumptions about how market participants would price the assets and liabilities.
Fair Value of Financial Instruments. The Company’s other financial instruments consist of cash and cash equivalents, certificates of deposit, receivables and payables. The carrying amounts of cash and cash equivalents, receivables and payables approximate fair value due to the highly liquid or short-term nature of these instruments.
Other Fair Value Measurements. The initial measurement of asset retirement obligations at fair value is calculated using discounted future cash flows of internally estimated costs. Significant Level 3 inputs used in the calculation of asset retirement obligations include the costs of plugging and abandoning wells, surface restoration and reserve lives. Subsequent to initial recognition, revisions to estimated asset retirement obligations are made when changes occur for input values, which we review quarterly.
Note 9 — Income Taxes
We file a consolidated federal income tax return in the United States and various combined and separate filings in several state and local jurisdictions.
There were no unrecognized tax benefits nor any accrued interest or penalties associated with unrecognized tax benefits during the three months ended September 30, 2014. We believe we have appropriate support for the income tax positions taken and to be taken on our tax returns and that the accruals for tax liabilities are adequate for all open years based on our assessment of many factors including past experience and interpretations of tax law applied to the facts of each matter. The Company’s federal and state income tax returns are open to audit under the statute of limitations for the years ending June 30, 2010 through June 30, 2014.
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Evolution Petroleum Corporation And Consolidated Subsidiaries
Notes to Unaudited Consolidated Condensed Financial Statements
Our effective tax rate for any period may differ from the statutory federal rate due to (i) our state income tax liability in Louisiana; (ii) stock-based compensation expense related to qualified incentive stock option awards (“ISO awards”), which creates a permanent tax difference for financial reporting, as these types of awards, if certain conditions are met, are not deductible for federal tax purposes; and (iii) statutory percentage depletion, which may create a permanent tax difference for financial reporting.
We recognized income tax expense of $706,159 and $482,636 for the three months ended September 30, 2014 and 2013, respectively, with corresponding effective rates of 38.5% and 24.7%.
Note 10 — Net Income Per Share
The following table sets forth the computation of basic and diluted income per share:

|  | Three Months Ended September 30,
|  | 2014 |  | 2013
Numerator |  |  |  |  |  |
Net income available to common shareholders |  | $ | 960,435 |  |  | $ | 1,303,876 |
Denominator |  |  |  |  |  |
Weighted average number of common shares — Basic |  | 32,682,401 |  |  | 28,607,320 |
Effect of dilutive securities: |  |  |  |  |  |
Weighted average of contingent restricted stock grants |  | 1,552 |  |  | — |
Weighted average of stock options |  | 142,297 |  |  | 3,603,945 |
Weighted average number of common shares and dilutive potential common shares used in diluted EPS |  | 32,826,250 |  |  | 32,211,265 |
Net income per common share — Basic |  | $ | 0.03 |  |  | $ | 0.05 |
Net income per common share — Diluted |  | $ | 0.03 |  |  | $ | 0.04 |

Outstanding potentially dilutive securities as of September 30, 2014 were as follows:

Outstanding Potential Dilutive Securities | Weighted Average Exercise Price |  | At September 30, 2014
Contingent restricted stock grants | $ | — |  |  | 56,286 |
Stock options | $ | 2.08 |  |  | 178,061 |
| $ | 1.58 |  |  | 234,347 |

Outstanding potentially dilutive securities as of September 30, 2013 were as follows:

Outstanding Potential Dilutive Securities | Weighted Average Exercise Price |  | At September 30, 2013
Stock options | $ | 1.99 |  |  | 4,822,820 |

Note 11 - Unsecured Revolving Credit Agreement
On February 29, 2012, Evolution Petroleum Corporation entered into a Credit Agreement (the “Credit Agreement”) with Texas Capital Bank, N.A. (the “Lender”). The Credit Agreement provides us with a revolving credit facility (the “facility”) in an amount up to $50,000,000 with availability governed by an Initial Borrowing Base of $5,000,000. A portion of the facility not in excess of $1,000,000 is available for the issuance of letters of credit.
The facility is unsecured and has a term of four years. Our subsidiaries guaranteed the Company’s obligations under the facility. We may use the proceeds of any loans under the facility for the acquisition and development of oil and gas properties, as defined in the facility, the issuance of letters of credit, and for working capital and general corporate purposes.
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Evolution Petroleum Corporation And Consolidated Subsidiaries
Notes to Unaudited Consolidated Condensed Financial Statements
Semi-annually, the borrowing base and a monthly reduction amount are re-determined from reserve reports. Requests by the Company to increase the $5,000,000 initial amount are subject to the Lender’s credit approval process, and are also limited to 25% of the value of our oil and gas properties, as defined.
At our option, borrowings under the facility bear interest at a rate of either (i) an Adjusted LIBOR rate (LIBOR rate divided by the remainder of 1 less the Lender’s Regulation D reserve requirement), or (ii) an adjusted Base Rate equal to the greater of the Lender’s prime rate or the sum of 0.50% and the Federal Funds Rate. A maximum of three LIBOR based loans can be outstanding at any time. Allowed loan interest periods are one, two, three and six months. LIBOR interest is payable at the end of the interest period except for six-month loans for which accrued interest is payable at three months and at end of term. Base Rate interest is payable monthly. Letters of credit bear fees reflecting 3.5% per annum rate applied to their principal amounts and are due when transacted. The maximum term of letters of credit is one year.
A commitment fee of 0.50% per annum accrues on unutilized availability and is payable quarterly. We are responsible for certain administrative expenses of the Lender over the life of the Credit Agreement as well as $50,000 in loan costs incurred upon closing.
The Credit Agreement also contains financial covenants including a requirement that we maintain a current ratio of not less than 1.5 to 1; a ratio of total funded Indebtedness to EBITDA of not more than 2.5 to 1, and a ratio of EBITDA to interest expense of not less than 3 to 1. The agreement specifies certain customary covenants, including restrictions on the Company and its subsidiaries from pledging their assets, incurring defined Indebtedness outside of the facility other that permitted indebtedness, and it restricts certain asset sales. Payments of dividends for the Series A Preferred are only restricted by the EBITDA to interest coverage ratio, wherein Series A dividends are a 1 X deduction from EBITDA (as opposed to a 3:1 requirement if dividends were treated as interest expense). The Credit Agreement contains customary events of default. If an event of default occurs and is continuing, the Lender may declare all amounts outstanding under the Credit Agreement, if any, to be immediately due and payable.
As of September 30, 2014, the Company had no borrowings and no outstanding letters of credit issued under the facility, resulting in an available borrowing base capacity of $5,000,000, and we are in compliance with all the covenants of the
Credit Agreement. During May 2014, the Credit Agreement was amended to permit the payment of cash dividends on common stock if no borrowings are outstanding at the time of such payment.
In connection with this agreement we incurred $179,468 of debt issuance costs, which have been capitalized in Other Assets and are being amortized on a straight-line basis over the term of the agreement. The unamortized balance in debt
issuance costs related to the Credit Agreement was $68,888 as of September 30, 2014. The Company is in discussions with the
Lender to replace the unsecured Credit Agreement with an expanded secured facility. As of September 30, 2014, the Company had incurred approximately $88,251 in legal and title costs related to this proposed agreement, which are also capitalized in Other Assets.
Note 12 — Commitments and Contingencies
We are subject to various claims and contingencies in the normal course of business. In addition, from time to time, we receive communications from government or regulatory agencies concerning investigations or allegations of noncompliance with laws or regulations in jurisdictions in which we operate. At a minimum we disclose such matters if we believe it is reasonably possible that a future event or events will confirm a loss through impairment of an asset or the incurrence of a liability. We accrue a loss if we believe it is probable that a future event or events will confirm a loss and we can reasonably estimate such loss and we do not accrue future legal costs related to that loss. Furthermore, we will disclose any matter that is unasserted if we consider it probable that a claim will be asserted and there is a reasonable possibility that the outcome will be unfavorable. We expense legal defense costs as they are incurred. For legal proceedings, see “Part II, Item 1. Legal Proceedings.”
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Evolution Petroleum Corporation And Consolidated Subsidiaries
Notes to Unaudited Consolidated Condensed Financial Statements
Lease Commitments. We have a non-cancelable operating lease for office space that expires on August 1, 2016. Future minimum lease commitments as of September 30, 2014 under this operating lease are as follows:

For the twelve months ended September 30, |
2015 | $ | 159,011 |
2016 | 132,509 |
Total | $ | 291,520 |

Rent expense for the three months ended September 30, 2014 and 2013 was $43,776 and $41,918, respectively.
Employment Contracts. We have entered into employment agreements with two of the Company's senior executives.
The employment contracts provide for severance payments in the event of termination by the Company for any reason other
than cause or permanent disability, or in the event of a constructive termination, as defined. The agreements provide for the
payment of base pay and certain medical and disability benefits for periods ranging from six months to one year after termination. The total contingent obligation under the employment contracts as of September 30, 2014 is approximately $473,000.
Note 13 — Subsequent Events
On October 24, 2014, the Company sold all of its joint venture interests in its Mississippian Lime properties in Kay County, Oklahoma for approximately $400,000, net of customary closing adjustments, and the buyer's assumption of all abandonment liabilities.
Denbury Resources, Inc., operator of the Delhi Field in northeast Louisiana, has informed the Company of its preliminary determination that payout occurred during the month of October 2014 and that the Company will earn its reversionary working interest of 23.9% and associated revenue interest of 19.1% in the Delhi Field effective November 1, 2014. When combined with our existing 7.4% royalty and overriding royalty interests, our total net revenue interest will increase to 26.5%, while we will now be responsible for paying 23.9% of the operating costs and capital expenditures going forward.
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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis should be read in conjunction with our consolidated financial statements and notes thereto contained herein and in our Annual Report on Form 10-K for the year ended June 30, 2014 (the “Form 10-K”), along with Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in the Form 10-K. Any terms used but not defined herein have the same meaning given to them in the Form 10-K.
This Form 10-Q and the information referenced herein contain forward-looking statements within the meaning of the Private Securities Litigations Reform Act of 1995, Section 27A of the Securities Act of 1933 (the “Securities Act”) and Section 21E of the Securities Exchange Act of 1934. The words “plan,” “expect,” “project,” “estimate,” “assume,” “believe,” “anticipate,” “intend,” “budget,” “forecast,” “predict” and other similar expressions are intended to identify forward-looking statements. These statements appear in a number of places and include statements regarding our plans, beliefs or current expectations, including the plans, beliefs and expectations of our officers and directors. When considering any forward-looking statement, you should keep in mind the risk factors that could cause our actual results to differ materially from those contained in any forward-looking statement. Important factors that could cause actual results to differ materially from those in the forward-looking statements herein include the timing and extent of changes in commodity prices for oil and natural gas, operating risks and other risk factors as described in our 2014 Annual Report on Form 10-K for the year ended June 30, 2014 as filed with the Securities and Exchange Commission. Furthermore, the assumptions that support our forward-looking statements are based upon information that is currently available and is subject to change. We specifically disclaim all responsibility to publicly update any information contained in a forward-looking statement or any forward-looking statement in its entirety and therefore disclaim any resulting liability for potentially related damages. All forward-looking statements attributable to Evolution Petroleum Corporation are expressly qualified in their entirety by this cautionary statement.
We use the terms, “EPM,” “Company,” “we,” “us” and “our” to refer to Evolution Petroleum Corporation and its wholly owned subsidiaries.
Executive Overview
General
We are engaged primarily in the development of incremental oil and gas reserves within known oil and gas resources for our shareholders and customers utilizing conventional and proprietary technology. We are focused on increasing underlying asset values on a per share basis. In doing so, we depend on a conservative capital structure, allowing us to maintain control of our assets for the benefit of our shareholders, and a substantial stock ownership by our directors, officers and staff. By policy, every employee and director maintains a beneficial ownership of our common stock.
Our strategy is to grow the value of our Delhi asset to maximize the value realized by our shareholders while commercializing our patented GARP® artificial lift technology for recovering incremental oil and gas reserves in mature fields.
We expect to fund our fiscal 2015 capital program from working capital and net cash flows from our properties.
Highlights for our First Quarter Fiscal 2015 and Project Update
“Q1-15” & “current quarter” is the three months ended September 30, 2014, the company’s 1st quarter of fiscal 2015.
“Q4-14” & “prior quarter” is the three months ended June 30, 2014, the company’s 4th quarter of fiscal 2014.
“Q1-14” & “year-ago quarter” is the three months ended September 30, 2013, the company’s 1st quarter of fiscal 2014.
Operations
· For Q1-15, we earned $1.0 million, or $0.03 per diluted common share, a 26% decrease from the year-ago quarter and a 33% decline from the previous quarter.
· Current quarter revenues were $4.0 million, a 14% decrease from the year-ago quarter and a 7% decline from the previous quarter.
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· Delhi production averaged 425 net barrels of oil per day (“BOPD”) (5,739 BOPD gross), a 3% decrease from both the previous quarter and the year-ago quarter. Realized price per barrel declined 4.6% from the previous quarter and 10% from the year-ago quarter to $98.96 per barrel.
· We remain debt-free, while distributing $3.3 million to our common shareholders in the form of cash dividends.
Projects
Additional property and project information is included under Item 1. Business, Item 2. Properties, Notes to the Financial Statements and Exhibit 99.4 of our Form 10-K for the year ended June 30, 2014.
Delhi Field EOR—Northeast Louisiana
Gross production at Delhi in the first quarter of fiscal 2015 was 5,739 BOPD, down 3% from the fourth quarter of the last fiscal year and down 3% from the year ago quarter. As previously disclosed, the operator has deferred capital spending in the field since early 2013 pending reversion of our working interest, and has also chosen to operate the field at a slightly lower reservoir pressure, which lowers the rate of oil production without reducing miscibility or lowering ultimate reserves.
We have been informed by the operator of its preliminary determination that payout occurred during the month of October 2014 and the Company will earn its approximate reversionary working interest of 23.9% (with related 19.1% net revenue interest) in the Delhi Field effective November 1, 2014. With this reversion, we and the operator have plans to resume expansion of the CO2 flood to the east and begin construction of a recycle gas processing plant in the field to recover methane and natural gas liquids while making the flood more efficient. We believe that these actions bode well for future increases in production rates from the field.
GARP® - Artificial Lift Technology
During the quarter, we completed the installation of GARP® in one well for a third party operator and started the installation of a second well. The second of the two installations was in progress at the end of the quarter. We removed the tangible equipment from a previous installation for this customer in which wellbore obstructions limited production, and utilized it on the first of these two wells. We have seen a positive response from the first two productive GARP® wells under this agreement completed during the previous quarter, although high operating costs and a low net-back from gas processing under the customer’s pre-existing gas sales contract in the first few months have limited the revenues from our net profits interest.
Artificial lift financial results were adversely affected by major workover operations on two of our three Company-operated wells, which temporarily suspended production during portions of the quarter and substantially reduced GARP® revenues.
Other Properties
Subsequent to the end of the quarter, we closed on the sale of all of our remaining interests in the Mississippian Lime project for cash proceeds of approximately $400,000, subject to customary closing adjustments. This transaction completes the process of divesting of all of our non-core oil and gas properties which we commenced in 2013.
Liquidity and Capital Resources
At September 30, 2014, our working capital was $21.9 million, compared to working capital of $23.3 million at June 30, 2014. The major factors which resulted in the $1.4 million decrease were the payment of $1.5 million in annual incentive compensation in September 2014 that reduced our net cash flow from operations and the payment of $3.3 million of common stock dividends in the current quarter.
Cash Flows from Operating Activities
For the three months ended September 30, 2014, cash flows provided by operating activities were $0.6 million, reflecting $1.6 million provided by operations before $1.0 million used by other working capital changes, primarily for the payment of annual incentive compensation. Of the $1.6 million provided before working capital changes, $1.1 million was due to net income, and $0.5 million was attributable to non-cash expenses.
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For the three months ended September 30, 2013, cash flows provided by operating activities were $1.6 million, reflecting $2.3 million provided by operations before $0.7 million was used in working capital. Of the $2.3 million provided before working capital changes, $1.5 million was due to net income and $0.8 million was due primarily to non-cash expenses.
Cash Flows from Investing Activities
Investing activities for the three months ended September 30, 2014 used $213,000 of cash, consisting primarily of $151,000 for artificial lift technology capital equipment and $55,000 for GARP® patent costs.
Cash paid for oil and gas capital expenditures during the three months ended September 30, 2013 was $594,000. Development activities were predominantly for GARP® installations in Giddings and additional testing in the Hendrickson well in the Mississippi Lime. We received approximately $67,000 of additional proceeds related to the June 2013 sale of certain of our Giddings Field properties.
Cash Flows from Financing Activities
In the three months ended September 30, 2014, we used $3.0 million in cash for financing activities principally consisting of cash outflows of $3.3 million for common stock dividend payments and $169,000 for preferred dividend payments, offset partially by $537,000 of cash provided by tax benefits related to stock-based compensation.
In the three months ended September 30, 2013, we paid preferred dividends of $169,000 and purchased $117,000 of treasury stock through the stock surrender of certain employees in satisfaction of payroll liabilities for contemporaneous restricted stock vesting.
Capital Budget
Delhi Field
With the operator's determination that reversion of our 23.9% working interest and 19.1% net revenue interest in Delhi occurred effective November 1, 2014, we will begin funding our share of capital and operating expenditures in the Field. Projected capital expenditures over the next two fiscal years are currently expected to total approximately $25-27 million net to our working interest. The timing of this spending is dependent on the pace of project development by the operator of the Field. Of this total, approximately $15-17 million is for the gas processing plant and approximately $10 million is for the roll-out of the next phase of the CO 2 project. We expect these costs to be incurred over portions of the next two fiscal years. Total spending based on proved reserves in the reserve report, net to our interest, is forecast to be approximately $45 million over the next four years, which includes the projects above plus further expansion of the CO 2 flood patterns. We expect that cash flows from our interests in the Field will be in excess of the net capital expenditures required.
GARP® - Artificial Lift Technology
Based on our current marketing and business plans, we expect that our capital requirements for artificial lift technology operations will be relatively modest over the next fiscal year.
Liquidity Outlook
Funding for all capital expenditures is expected to be met from current working capital and cash flows from operations. Our preference is to remain debt free, but we do have access to a $5 million unsecured revolving line of credit and are in discussions to convert this line to a senior secured facility with up to $30 million of capacity. This facility is intended primarily to provide a standby source of liquidity to meet future capital expenditures at Delhi or other future capital needs or opportunities.
Payment of cash dividends on our common stock remains an important aspect of our financial strategy and it is our goal to maintain or increase our dividends. We expect that the excess cash flow from the Delhi Field, after reversion of our working interest, will permit the Board of Directors to begin considering prudent increases in the level of our dividend payout during Fiscal 2016.
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Results of Operations
Three month periods ended September 30, 2014 and 2013
The following table sets forth certain financial information with respect to our oil and natural gas operations:

| Three Months Ended September 30, |  |  |  |
| 2014 |  | 2013 |  | Variance |  | Variance %
Delhi field: |  |  |  |  |  |  |
Crude oil revenues | $ | 3,868,602 |  |  | $ | 4,429,811 |  |  | $ | (561,209 | ) |  | (12.7 | )%
Crude oil volumes (Bbl) | 39,094 |  |  | 40,279 |  |  | (1,185 | ) |  | (2.9 | )%
Average price per Bbl | $ | 98.96 |  |  | $ | 109.98 |  |  | $ | (11.02 | ) |  | (10.0 | )%
Artificial lift technology: |  |  |  |  |  |  |
Crude oil revenues | $ | 74,980 |  |  | $ | 101,873 |  |  | $ | (26,893 | ) |  | (26.4 | )%
NGL revenues | 22,227 |  |  | 23,196 |  |  | (969 | ) |  | (4.2 | )%
Natural gas revenues | 15,552 |  |  | 17,022 |  |  | (1,470 | ) |  | (8.6 | )%
Service revenue | $ | 3,097 |  |  | $ | — |  |  | 3,097 |  |  |
Total revenues | $ | 115,856 |  |  | $ | 142,091 |  |  | $ | (26,235 | ) |  | (18.5 | )%
Crude oil volumes (Bbl) | 772 |  |  | 946 |  |  | (174 | ) |  | (18.4 | )%
NGL volumes (Bbl) | 744 |  |  | 768 |  |  | (24 | ) |  | (3.1 | )%
Natural gas volumes (Mcf) | 4,439 |  |  | 5,889 |  |  | (1,450 | ) |  | (24.6 | )%
Equivalent volumes (BOE) | 2,256 |  |  | 2,696 |  |  | (440 | ) |  | (16.3 | )%
Crude oil price per Bbl | $97.12 |  | $107.69 |  | $ | (10.57 | ) |  | (9.8 | )%
NGL price per Bbl | $29.88 |  | $30.20 |  | (0.32 | ) |  | (1.1 | )%
Natural gas price per Mcf | $3.50 |  | $2.89 |  | 0.61 |  |  | 21.1 | %
Equivalent price per BOE | $49.98 |  | $52.70 |  | $ | (2.72 | ) |  | (5.2 | )%
Artificial lift production costs (b) | $ | 197,360 |  |  | $ | 163,749 |  |  | $ | 33,611 |  |  | 20.5 | %
Artificial lift production costs per BOE | 87.48 |  |  | 60.74 |  |  | $ | 26.74 |  |  | 44.0 | %
Other properties: |  |  |  |  |  |  |
Revenues | $ | 20,369 |  |  | $ | 61,797 |  |  | $ | (41,428 | ) |  | (67.0 | )%
Equivalent volumes (BOE) | 285 |  |  | 668 |  |  | (383 | ) |  | (57.3 | )%
Equivalent price per BOE | $ | 71.47 |  |  | $ | 92.51 |  |  | $ | (21.04 | ) |  | (22.7 | )%
Production costs | $ | 88,022 |  |  | $ | 254,501 |  |  | $ | (166,479 | ) |  | (65.4 | )%
Production costs per BOE | $ | 308.85 |  |  | $ | 380.99 |  |  | $ | (72.14 | ) |  | (18.9 | )%
Combined: |  |  |  |  |  |  |
Oil and gas DD&A (a) | $ | 260,160 |  |  | $ | 301,752 |  |  | $ | (41,592 | ) |  | (13.8 | )%
Oil and gas DD&A per BOE | $ | 6.25 |  |  | $ | 6.91 |  |  | $ | (0.66 | ) |  | (9.6 | )%

(a) Excludes depreciation of artificial lift technology equipment, office equipment, furniture and fixtures, and other assets of $109,190 and $7,921, for the three months ended September 30, 2014 and 2013, respectively.
(b) Includes workover costs of approximately $149,000 and $42,000, for the three months ended September 30, 2014 and 2013, respectively. Note: There were three producing wells in the period ending 2014 versus four in the period ending 2013.
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Net Income Available to Common Shareholders. For the quarter ended September 30, 2014, we generated net income to common shareholders of $1.0 million, or $0.03 per diluted share, on total revenues of $4.0 million. This compares to net income of $1.3 million, or $0.04 per diluted share, on total revenues of $4.6 million for the year-ago quarter. The earnings decline is due to lower revenue and a higher effective income tax rate, partially offset by lower general and administrative expenses. Additional details of the components of net income are explained in greater detail below.
Delhi Field. Revenues decreased 13% to $3.9 million as a result of a 3% decline in production volumes from the year ago quarter and a 10% decline in realized crude oil prices, from $109.98 per barrel to $98.96 per barrel. There are no production costs in the Delhi Field, as all current revenues derive from mineral and overriding royalty interests.
Artificial Lift Technology. Revenues decreased 19% to $116,000 reflecting a 16% volume decrease, primarily as a result of workovers on the Philip DL #1 and Selected Lands #2 wells, together with a 5% decrease in the realized price per BOE. We recorded $3,000 of service revenue from the recent GARP® initial installations for a third-party customer. Those two wells did not contribute meaningful net profits to the Company in this quarter, but we believe they will do so in future quarters. Artificial lift production costs were $197,000, which included $149,000 in costs for the above workovers, which were successful in increasing production.
Other Properties. The Company has been divesting its non-core oil and gas properties since 2013, and revenues have correspondingly decreased to $20,000 compared to $62,000 in the year-ago quarter. The production costs from the prior year were high as a result primarily from workover costs in South Texas and high water production in the Mississippian Lime. With the sale of the remaining interests in our Mississippian Lime properties subsequent to the end of the quarter, this divestiture process is now completed.
General and Administrative Expenses (“G&A”). G&A expenses decreased $0.4 million, or 22%, to $1.5 million during the three months ended September 30, 2014 from $1.9 million in the year-ago quarter primarily due to lower personnel-related costs as a result of our December 2013 restructuring, partially offset by recent staff additions for GARP®. Salaries and benefits declined $231,000, incentive compensation decreased $60,000 and stock-based compensation expense declined by $130,000.
Depletion & Amortization Expense (“DD&A”). DD&A increased $60,000, or 19%, to $369,000 for the current quarter compared to $310,000 for the year-ago quarter. DD&A of our oil and gas properties decreased by $41,000 on lower production and a lower rate per BOE ($6.25 versus $6.91 per BOE in the year-ago quarter), while our other DD&A increased by $101,000. This increase primarily includes depreciation of $21,000 related to artificial lift equipment installed in the wells of a third-party customer and a charge of $77,000 to expense the unrecovered installation costs of artificial lift equipment which was removed from one well and reinstalled in another well of a third-party customer.
Other Economic Factors
Inflation. Although the general inflation rate in the United States, as measured by the Consumer Price Index and the Producer Price Index, has been relatively low in recent years, the oil and gas industry has experienced unusually volatile price movements in commodity prices, vendor goods and oilfield services. Prices for drilling and oilfield services, oilfield equipment, tubulars, labor, expertise and other services greatly impact our production costs and capital expenditures. During fiscal 2014, we saw modest increases in certain oil field services and materials compared to the prior fiscal year. During fiscal 2015 to date, we have not seen material increases in costs. Product prices, operating costs and development costs may not always move in tandem.
Known Trends and Uncertainties. General worldwide economic conditions continue to be uncertain and volatile. Concerns over uncertain future economic growth are affecting numerous industries, companies, as well as consumers, which impact demand for crude oil and natural gas. We have recently seen significant declines in crude oil prices and are uncertain if this downward price pressure will continue. If such lower crude oil prices persist, our revenues and cash flow going forward will be adversely impacted. In addition, reversion of our working interest in the Delhi Field will increase both our revenues and lease operating expenses. This will reduce the extraordinary net margins that have resulted from our mineral and overriding royalty interests at Delhi.
Seasonality. Our business is generally not directly seasonal, except for instances when weather conditions may adversely affect access to our properties or delivery of our petroleum products. Although we do not generally modify our production for changes in market demand, we do experience seasonality in the product prices we receive, driven by summer cooling and driving, winter heating, and extremes in seasonal weather including hurricanes that may substantially affect oil and natural gas production and imports.
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Off Balance Sheet Arrangements
The Company has no off-balance sheet arrangements to report during the quarter ending September 30, 2014.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISKS
Information about market risks for the three months ended September 30, 2014, did not change materially from the disclosures in Item 7A of our Annual Report on Form 10-K for the year ended June 30, 2014.
Commodity Price Risk
O ur most significant market risk is the pricing for crude oil, natural gas and NGLs. We expect energy prices to remain volatile and unpredictable. If energy prices decline significantly, revenues and cash flow would significantly decline. In addition, a non-cash write-down of our oil and gas properties could be required under full cost accounting rules if future oil and gas commodity prices sustained a significant decline. Prices also affect the amount of cash flow available for capital expenditures and our ability to borrow and raise additional capital, as, if and when needed. Our general philosophy is not to hedge our commodity price risk. If we chose, we could hedge a portion of our projected oil and natural gas production through a variety of financial and physical arrangements intended to support oil and natural gas prices at targeted levels and to manage our exposure to price fluctuations. We presently do not hold or issue derivative instruments for hedging or speculative purposes.
Interest Rate Risk
We currently have only a small exposure to changes in interest rates. Changes in interest rates affect the interest earned on our cash and cash equivalents. Under our current policies, we do not use interest rate derivative instruments to manage exposure to interest rate changes.
ITEM 4. CONTROLS AND PROCEDURES
We maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in our Exchange Act reports 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 this Company’s management, including our Chief Executive Officer and Chief Financial Officer, as appropriate to allow for timely decisions regarding required disclosure.
As required by Securities and Exchange Commission Rule 13a-15(b), we carried out an evaluation, under the supervision and with the participation of the Company’s management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(c) and 15d-15(e)) as of the end of the quarter covered by this report. In designing and evaluating our disclosure controls and procedures, our management recognizes that controls and procedures, no matter how well designed and operated, can provide only reasonable assurance of achieving desired control objectives. Based on the foregoing, our Chief Executive Officer and Chief Financial Officer concluded that as of September 30, 2014 our disclosure controls and procedures are effective in ensuring that the information required to be disclosed in our reports filed or submitted under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the Securities and Exchange Commission rules and forms.
Under the supervision and with the participation of the Company’s management, including its Chief Executive Officer and Chief Financial Officer, during the quarter ended September 30, 2014 we have determined there has been no change in our internal control over financial reporting that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.
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PART II - OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS ITEM 1.
We are involved in certain legal proceedings that are described in Part I. Item 3. “Legal Proceedings” and Note 15 — Commitments and Contingencies under Part II. Item 8. “Financial Statements” in our 2014 Annual Report. During the quarter ended September 30, 2014, there were no material developments in the status of those proceedings except as described below. We believe that the ultimate liability, if any, with respect to these other claims and legal actions will not have a material effect on our financial position or on our results of operations.
The Company and its wholly owned subsidiary are defendants in a lawsuit brought by John C. McCarthy et. al in the fifth District Court of Richland Parish, Louisiana in July 2011. The plaintiffs alleged, among other claims, that we fraudulently and wrongfully purchased plaintiffs’ income royalty rights in the Delhi Field Unit in the Holt-Bryant Reservoir in May 2006. On March 29, 2012, the Fifth District Court dismissed the case against the Company and our wholly owned subsidiary NGS Sub Corp. The Court found that plaintiffs had “no cause of action” under Louisiana law, assuming that the Plaintiff’s claims were valid on their face. Plaintiffs filed an appeal and the Louisiana Second Circuit Court of Appeal affirmed the dismissal, but allowed the plaintiffs to amend their petition to state a different possible cause of action. The plaintiffs amended their claim and re-filed with the district court. The plaintiffs are seeking cancellation of the transaction and monetary damages. We subsequently filed a second motion pleading “no cause of action,” with which the district court again agreed and dismissed the plaintiffs’ case on September 23, 2013. Plaintiffs again filed an appeal in November 2013. In October 2014, the appellate court reversed the district court. We subsequently filed for a rehearing.
As previously reported, on August 23, 2012, we and our wholly-owned subsidiary, NGS Sub Corp., and Robert S. Herlin, our President and Chief Executive Officer, were served with a lawsuit filed in federal court by James H. and Kristy S. Jones (the “Jones lawsuit”) in the Western District Court of the Monroe Division, Louisiana. The plaintiffs allege primarily that we (defendants) wrongfully purchased the plaintiffs’ 0.048119 overriding royalty interest in the Delhi Unit in January 2006 by failing to divulge the existence of an alleged previous agreement to develop the Delhi Field for EOR. The plaintiffs are seeking rescission of the assignment of the overriding royalty interest and monetary damages. We believe that the claims are without merit and are not timely, and we are vigorously defending against the claims. We filed a motion to dismiss for failure to state a claim under Federal Rule of Civil Procedure 12(b) (6) on April 1, 2013. On September 17, 2013, the federal court in the Western District Court of the Monroe Division, Louisiana, dismissed a portion of the claims and allowed the plaintiffs to pursue the remaining portion of the claims. Our motion to dismiss was for lack of cause of action, assuming that the plaintiffs' claims were valid on their face. On September 25, 2013, plaintiff Jones filed a motion to alter or amend the September 17, 2013 judgment. On December 27, 2013, the court denied said plaintiffs’ motion, and on January 21, 2014, we filed a motion to reconsider the nondismissal of the remaining claims, which was denied. Counsel has advised us that, based on information developed to date, the risk of loss in this matter is remote.
On December 13, 2013, we and our wholly-owned subsidiaries, Tertiaire Resources Company and NGS Sub. Corp., filed a lawsuit in the 133rd Judicial District Court of Harris County, Texas, against Denbury Onshore, LLC (“Denbury”) alleging breaches of certain 2006 agreements between the parties regarding the Delhi Field in Richland Parish, Louisiana. The specific allegations include improperly charging the payout account for capital expenditures and costs of capital, failure to adhere to preferential rights to participate in acquisitions within the defined area of mutual interest, breach of the promises to assume environmental liabilities and fully indemnify us from such costs, and other breaches. We are seeking declaration of the validity of the 2006 agreements and recovery of damages and attorneys’ fees. Denbury subsequently filed counterclaims, including the assertion that we owed Denbury additional revenue interests pursuant to the 2006 agreements and that our transfer of the reversionary interests from our wholly owned subsidiary to our parent corporation and subsequently to another wholly-owned subsidiary were not timely noticed to Denbury.
On December 3, 2013, our wholly owned subsidiary, NGS Sub. Corp., was served with a lawsuit filed in the 8th Judicial District Court of Winn Parish, Louisiana by Cecil M. Brooks, a resident of Louisiana, alleging that a former subsidiary of NGS Sub. Corp. improperly disposed of water from an off-lease well into a well located on the plaintiff’s land in Winn Parish in 2006. The plaintiff is requesting monetary damages and other relief. NGS Sub. Corp. disposed of the property in question along with its ownership of the subsidiary in 2008 to a third party. We have denied the claims.
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ITEM 1A. RISK FACTORS
Our Annual Report on Form 10-K for the year ended June 30, 2014 includes a detailed discussion of our risk factors. There have been no material changes to the risk factors previously disclosed in our Annual Report on Form 10-K for the year ended June 30, 2014.
ITEM 2. UNREGISTERED SALE OF EQUITY SECURITIES AND USE OF PROCEEDS
During the quarter ended September 30, 2014, the Company did not sell any equity securities that were not registered under the Securities Act.
Issuer Purchases of Equity Securities
During the quarter ended September 30, 2014, the Company received shares of common stock from employees of the Company to pay their share of payroll taxes arising from vestings of restricted stock and exercises of stock options. The acquisition cost per share reflected the weighted-average market price of the Company’s shares of capital stock at the dates of exercise or restricted stock vesting.

Period |  | (a) Total Number of Shares (or Units) Purchased |  | (b) Average Price Paid per Share (or Units) |  | (c) Total Number of Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs |  | (d) Maximum Number (or Approximate Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs
July 1, 2014 to July 31, 2014 |  | 99 shares of Common Stock |  | $ | 10.94 |  |  | Not applicable |  | Not applicable
August 1, 2014 to August 31, 2014 |  | none |  |  |  | Not applicable |  | Not applicable
September 1, 2014 to September 30, 2014 |  | 5,530 shares of Common Stock |  | $ | 9.83 |  |  | Not applicable |  | Not applicable

ITEM 3. DEFAULTS UPON SENIOR SECURITIES
Not applicable.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
ITEM 5. OTHER INFORMATION
None.
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ITEM 6. EXHIBITS
A. Exhibits

4.1 |  | Form of Contingent Performance Stock Grant under the Evolution Petroleum Corporation Amended and Restated 2004 Stock Plan (Filed herein)
31.1 |  | Certification of Chief Executive Officer pursuant to Rule 13a-14(a) or Rule 15d-14(a) under the Securities Exchange Act of 1934, as amended.
31.2 |  | Certification of Chief Financial Officer pursuant to Rule 13a-14(a) or Rule 15d-14(a) under the Securities Exchange Act of 1934, as amended.
32.1 |  | Certification of Chief Executive Officer pursuant to18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2 |  | Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS |  | XBRL Instance Document
101.SCH |  | XBRL Taxonomy Extension Schema Document
101.CAL |  | XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF |  | XBRL Taxonomy Extension Definition Linkbase Document
101.LAB |  | XBRL Taxonomy Extension Label Linkbase Document
101.PRE |  | XBRL Taxonomy Extension Presentation Linkbase Document

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SIGNATURES
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.
EVOLUTION PETROLEUM CORPORATION
(Registrant)

|  | By: | /s/ RANDALL D. KEYS
|  |  | Randall D. Keys
|  |  | President and Chief Financial Officer
|  |  | Principal Financial Officer and
|  |  | Principal Accounting Officer
Date: November 7, 2014 |  |

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