Document


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 

FORM 8-K

 
CURRENT REPORT PURSUANT
TO SECTION 13 OR 15(D) OF THE
SECURITIES EXCHANGE ACT OF 1934
 
Date of Report (Date of earliest event reported): May 8, 2017
 

Evolution Petroleum Corporation
(Exact name of registrant as specified in its charter)
 

 
001-32942
(Commission File Number)
 
 
 
 
 
Nevada
 
41-1781991
(State or Other Jurisdiction of Incorporation)
 
(I.R.S. Employer Identification No.)
 
1155 Dairy Ashford Road, Suite 425, Houston, Texas 77079
(Address of Principal Executive Offices)
 
(713) 935-0122
(Registrant’s Telephone Number, Including Area Code)

 
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
 
o                    Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
 
o                    Soliciting material pursuant to Rule 14a-12 under the exchange Act (17 CFR 240.14a-12)
 
o                    Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
 
o                    Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

     Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
     Emerging growth company  o
 
     If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.   o




Item 2.02 Results of Operations and Financial Condition.
 
On May 8, 2017, Evolution Petroleum Corporation (the “Company”) issued a press release reporting on financial and operating results for the quarter ended March 31, 2017, the Company's 3th quarter of fiscal 2017.  A copy of the press release, dated May 8, 2017, is furnished herewith as Exhibit 99.1.
 
This information is furnished pursuant to Item 2.02 of Form 8-K and shall not be deemed filed for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), or otherwise subject to the liabilities of that section, unless specifically incorporated by reference in a document filed under the Securities Act of 1933, as amended, or the Exchange Act. By filing this report on Form 8-K and furnishing this information, the Company makes no admission as to the materiality of any information in this report that is required to be disclosed solely by Item 2.02.
 
Item 9.01.                                        Financial Statements and Exhibits.
 
(d)                                 Exhibits.
 
 
 
 
 
Exhibit No.
 
Description
 
 
 
Exhibit 99.1
 
Evolution Petroleum Corporation Press Release, dated May 8, 2017


2


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 hereunto duly authorized.
 
 
 
 
 
 
Evolution Petroleum Corporation
                   (Registrant)
 
 
Dated: May 9, 2017
By:
/s/ Randall D. Keys
 
Name:
Randall D. Keys
 
Title:
President and Chief Executive Officer


3


INDEX TO EXHIBITS
 
 
 
 
 
Exhibit No.
 
Description
Exhibit 99.1
 
Evolution Petroleum Corporation Press Release, dated May 8, 2017


4
Exhibit


Exhibit 99.1
https://cdn.kscope.io/98c4a8916e1547b2dc84bcf9d9bffa40-epclogoq3fy2017a01.jpg
Company Contact:
Randy Keys, CEO
(713) 935-0122
rkeys@evolutionpetroleum.com

Evolution Petroleum Announces Results for the
Fiscal 2017 Third Quarter Ended March 31, 2017 and
Declares Quarterly Common Stock Dividend

Houston, TX, May 8, 2017 - Evolution Petroleum today reported financial and operating highlights for its fiscal third quarter ended March 31, 2017, with comparisons to the fiscal second quarter ended December 31, 2016 (the "prior quarter") and the quarter ended March 31, 2016 (the "year-ago quarter").
Highlights for the Quarter:
Revenues for the fiscal third quarter of 2017 were $9.5 million, an increase of 87% over the third quarter of 2016.
Net income was $2.4 million in the third quarter of 2017, or $0.07 per diluted common share, versus a net loss of $298,000, or $0.01 per common diluted share, in the year ago quarter.
The Company paid its fourteenth consecutive quarterly cash dividend on common stock, in the amount of $0.07 per share, which reflected an 8% increase over the prior quarter.
Delhi natural gas liquid ("NGL") sales commenced in the current quarter. Gross NGL sales volumes averaged 830 barrels per day as volumes ramped up during the quarter. Our net NGL sales volumes were 218 barrels per day and the net realized NGL price was $23.71 per barrel.
Gross oil production in the Delhi field increased 2.7% over the prior quarter, increasing to 7,786 barrels of oil per day (“BOPD”) from 7,580 BOPD, continuing a positive trend of optimizing production in the CO2 flood. Our net oil production increased to 2,042 BOPD from 1,987 BOPD in the prior quarter and the net realized oil price per barrel was $49.29 compared to $46.66 in the prior quarter, an increase of 6%.
Lifting costs at Delhi were $13.82 per barrel, which represents a 10.2% increase over the prior quarter and a 5.3% increase over the year-ago quarter. The increase in lifting costs is almost entirely attributable to incremental costs for the NGL plant, which commenced operations at the beginning of the quarter.





The Company ended the quarter with $21.5 million of working capital, substantially all of which was cash. With essentially all of our capital spending for the NGL plant completed in the prior quarter, our working capital increased by $2.9 million, despite paying $2.3 million in quarterly common stock dividends.
The Company remains debt free.
“Oil production in the Delhi field continues its positive trend, with gross production increasing by over 200 BOPD from the prior quarter,” said Randy Keys, President and CEO. “We continue to see the benefits from diverse conformance workovers and performance enhancement projects designed to improve efficiency in use of the recycle CO2 stream. Further, these results have been achieved while reducing purchased CO2 volumes.
“Additionally, the Company began selling NGL’s from the NGL recovery plant during the quarter. This plant is designed to enhance the efficiency of the CO2 flood by purifying the recycle CO2 stream, produce high-value natural gas liquids for sale and also produce methane and ethane for conversion to electricity in the field. The NGL plant is meeting all objectives, and we are working through technical adjustments to continue to improve the production rates and efficiency of the process. The NGL plant is a very important milestone in the development of the Delhi field and for Evolution Petroleum.”
Results for the Quarter Ended March 31, 2017
In the current quarter, operating revenues were $9.5 million, based on an average realized oil price of $49.29 per barrel and an average NGL price of $23.71 per barrel, and generated $3.9 million in income from operations. In the year ago quarter, operating revenues were $5.1 million and we had a loss from operations of $0.7 million, based on an average oil price of $30.00 per barrel. Net oil production volumes were 2,042 BOPD, an increase of 11% from 1,834 BOPD in the year ago quarter. In addition, the Company added 218 barrels per day of higher-value natural gas liquids from start-up of the NGL plant, which were sold at a net realized price of $23.71 per barrel. Net income for the quarter was $2.4 million, or $0.07 per diluted share.
Production costs in the Delhi field were $2.8 million in the current quarter, up from $2.3 million in the prior quarter and $2.2 million in the year ago quarter. The current quarter includes approximately $0.5 million of incremental operating costs from the NGL plant, which accounts for almost all of the increase in costs from





the prior quarter. These costs include some non-recurring expenses associated with start-up of the NGL plant and do not yet reflect any significant savings in power costs from the electric generation capacity of the plant. Purchased CO2 volumes were 66.3 million cubic feet (MMcf) per day, unchanged from the prior quarter, and our total CO2 costs were also flat at approximately $1.0 million in each of the past two quarters.
General and administrative (“G&A”) expenses were $1.3 million for the quarter, of which $0.3 million were noncash stock-based compensation expenses and approximately $1.0 million were cash costs. These amounts were up slightly from the prior quarter, but represent a 44% reduction from the year-ago quarter, which included significant litigation costs. The Company made significant reductions in G&A costs since the downturn began, but we have recently incurred a small amount of discretionary costs in connection with the evaluation of potential producing property acquisitions.
Delhi Operations and Capital Spending
Gross oil production at Delhi averaged 7,786 BOPD during the quarter, a 2.7% increase from the prior quarter and an increase of 12.5% from the year-ago quarter. There continues to be increased production from conformance projects and other production enhancement operations. Gross NGL sales for this initial quarter of production were 830 barrels per day. After an initial startup period in January 2017, the NGL plant averaged approximately 1,100 barrels per day on a gross basis during February and March 2017. During these two months, the plant operated at 20% to 30% below its full capacity. Based on results seen in this initial operating period, we believe the plant should be able to achieve more than 1,400 barrels per day at full capacity. Startup of new processing plants often involves a period of adjustments to reach equilibrium operations and we are working with the operator to resolve the issues which are currently limiting full production capacity for the plant.
The NGL plant includes an electric turbine to convert methane and part of the ethane removed by the plant to electricity. This electricity will provide power to the NGL plant and is expected to supply excess power to the CO2 recycle facility, which is expected to reduce part of existing power costs in the Delhi field. During the first quarter of production, with the NGL plant operating at less than full capacity and ramping up the flow rate during the quarter, the Company has yet to see measurable savings in power costs. The NGL





plant is accomplishing its primary objective of removing the lighter hydrocarbons (i.e. methane and ethane), thereby increasing the purity of the CO2 recycle stream and improving the efficiency of the flood. Over time, this is expected to increase the recovery of crude oil in the field. The plant is also providing feedstock to power the electric turbine and producing significant quantities of higher value NGL's for sale.
Costs from inception of the NGL plant totaled $26.3 million, which is believed to represent substantially all the capital costs to be incurred. The final cost of the plant was within 8% of budget and differed primarily as a result of price increases on specialized components after the original estimate, and additional commissioning costs.
During the quarter, less than $0.2 million was spent on capital workover projects for conformance operations in the Delhi field. Current expectations for capital spending during the remainder of the fiscal year ended June 30, 2017 include a few additional conformance and workover operations totaling less than $1 million net to Evolution. These new projects result from the demonstrated benefits from previous conformance efforts and the significant returns that have been realized from relatively modest capital investments in the field. The Company has seen significant production increases from conformance projects over the past two years.
Based on recent meetings with the field operator, new opportunities have been identified to invest in the Delhi field during the second half of this calendar year, which is part of the fiscal 2018 plan. The majority of this capital is planned for an infill drilling program to enhance production in the current developed area of the flood. This program will consist of up to five new CO2 injection wells and seven new production wells and will target productive oil zones which are not being swept effectively by the current CO2 flood. This infill program is expected to both add production and increase ultimate recoveries above the current proved oil reserves. There are other capital projects proposed to add water injection infrastructure for the Phase Five expansion of the Delhi field so that it can be developed in a safe and responsible manner. The expansion is expected to occur during calendar 2018, subject to oil prices and other factors.





Liquidity and Capital Resources
Liquidity improved by $2.9 million and the Company ended the quarter with $21.5 million in working capital and $10 million of undrawn liquidity under its reserve-based credit facility. Our low cost structure provides solid cash flow, even in periods of weaker oil prices, and it is expected that capital needs will be relatively modest now that the NGL plant is complete. The Company expects to continue to generate significant free cash flow in the current oil price environment.
Cash Dividend on Common Stock
The Board of Directors declared a cash dividend of $0.07 per share of common stock, which will be paid on June 30, 2017 to common stockholders of record on June 15, 2017. This is the fifteenth consecutive quarterly cash dividend on the common stock, which has been paid since the end of calendar year 2013.
Quarterly Conference Call
For the past two quarters, Evolution has pre-recorded its quarterly conference call as a webcast audio commentary with associated slides. This presentation may be accessed at the following link:
https://www.brainshark.com/evolutionpetroleum/Qtr-Mar2017
It will also be available on the Company's website, www.EvolutionPetroleum.com, as soon as practical after the distribution of this quarterly earnings press release. This commentary, which is approximately 13 minutes in length, will be re-broadcast on Tuesday, May 9, 2017 at 11:00 a.m. Eastern Time (10:00 a.m. Central). The re-broadcast will be followed by a live question and answer session at approximately 11:15 a.m. Eastern Time (10:15 a.m. Central). To access the conference call by phone, please dial 1-855-327-6837 (US and Canada) or 1-631-891-4304 (International). To listen live via webcast or to hear a rebroadcast, please go to www.EvolutionPetroleum.com. A replay will be available two hours after the end of the conference call through May 16, 2017 by calling 1-844-512-2921 (US and Canada) or 1-412-317-6671 (International) and providing the replay pin number of 10002847.





Investor Conference Presentation
David Joe, Chief Financial Officer of Evolution, will present at the East Coast IDEAS Investor Conference on Thursday, May 18, 2017 at the Boston Park Plaza in Boston, Massachusetts. Evolution’s presentation is scheduled to begin at 11:20 a.m. Eastern Time (10:20 a.m. Central Time). The presentation will be webcast live and may be accessed at the conference website, www.IDEASConferences.com, or on the home page of the Company's website: www.EvolutionPetroleum.com.  The presentation materials will be available on the Company’s website the day of the event.
The IDEAS Investor Conferences are held annually in Boston, Chicago and Dallas and are produced by Three Part Advisors, LLC. 
About Evolution Petroleum
Evolution Petroleum Corporation develops and produces petroleum reserves within known oil and gas reservoirs in the U.S., with a focus on maximizing value per share. Our principal asset is our interest in a CO2 enhanced oil recovery project in Louisiana's Delhi Field. Additional information, including the Company's most recent annual report on Form 10-K and its quarterly reports on Form 10-Q, is available on its website at www.EvolutionPetroleum.com.
Cautionary Statement
All forward-looking statements contained in this press release regarding potential results and future plans and objectives of the Company involve a wide range risks and uncertainties. Statements herein using words such as "believe," "expect," "plans" and words of similar meaning are forward-looking statements. Although our expectations are based on engineering, geological, financial and operating assumptions that we believe to be reasonable, many factors could cause actual results to differ materially from our expectations and we can give no assurance that our goals will be achieved. These factors and others are detailed under the heading "Risk Factors" and elsewhere in our periodic documents filed with the SEC. The Company undertakes no obligation to update any forward-looking statement.





Company Contact:
Randy Keys, President and CEO
(713) 935-0122
rkeys@evolutionpetroleum.com




Financial Tables to Follow




Evolution Petroleum Corporation and Subsidiaries
Consolidated Condensed Statements of Operations
(Unaudited)
 


 
Three Months Ended
 
 
 
 
 
March 31,
 
December 31,
 
Nine Months Ended 
 March 31,
 
2017
 
2016
 
2016
 
2017
 
2016
Revenues
 

 
 

 
 
 
 

 
 

Crude oil
$
9,060,796

 
$
5,005,955

 
$
8,529,817

 
$
25,184,468

 
$
18,897,572

Natural gas liquids
464,641

 
597

 

 
464,730

 
2,332

Natural gas

 
183

 

 
(4
)
 
1,204

Artificial lift technology services

 
100,000

 

 

 
207,960

Total revenues
9,525,437

 
5,106,735

 
8,529,817

 
25,649,194

 
19,109,068

Operating costs
 
 
 
 
 
 
 
 
 
Production costs
2,811,258

 
2,192,217

 
2,292,421

 
7,448,320

 
7,030,537

Cost of artificial lift technology services

 
10,933

 

 

 
70,932

Depreciation, depletion and amortization
1,523,475

 
1,268,800

 
1,307,510

 
4,104,424

 
3,958,644

Accretion of discount on asset retirement obligations
13,562

 
11,695

 
13,106

 
39,892

 
34,555

General and administrative expenses *
1,283,906

 
2,304,237

 
1,241,399

 
3,760,348

 
6,046,603

Restructuring charges **

 

 

 

 
1,257,433

Total operating costs
5,632,201

 
5,787,882

 
4,854,436

 
15,352,984

 
18,398,704

Income (loss) from operations
3,893,236

 
(681,147
)
 
3,675,381

 
10,296,210

 
710,364

Other
 

 
 

 
 

 
 

 
 

Gain on realized derivative instruments, net
3,350

 
1,795,431

 

 
3,440

 
3,960,059

Gain (loss) on unrealized derivative instruments, net
47,965

 
(1,314,044
)
 

 
33,833

 
119,679

Delhi field insurance recovery related to pre-reversion event

 

 

 

 
1,074,957

Interest and other income
13,099

 
11,851

 
14,061

 
39,905

 
23,516

Interest expense
(20,317
)
 
(14,036
)
 
(20,711
)
 
(61,373
)
 
(51,162
)
Income (loss) before income taxes
3,937,333

 
(201,945
)
 
3,668,731

 
10,312,015

 
5,837,413

Income tax provision (benefit)
1,518,190

 
(72,337
)
 
1,361,097

 
3,768,463

 
2,051,521

Net income (loss) attributable to the Company
2,419,143

 
(129,608
)
 
2,307,634

 
6,543,552

 
3,785,892

Dividends on preferred stock

 
168,575

 

 
250,990

 
505,726

Deemed dividend on preferred shares called for redemption

 

 

 
1,002,440

 

Net income (loss) available to common stockholders
$
2,419,143

 
$
(298,183
)
 
$
2,307,634

 
$
5,290,122

 
$
3,280,166

Earnings (loss) per common share
 
 
 
 
 
 
 
 
 
Basic
$
0.07

 
$
(0.01
)
 
$
0.07

 
$
0.16

 
$
0.10

Diluted
$
0.07

 
$
(0.01
)
 
$
0.07

 
$
0.16

 
$
0.10

Weighted average number of common shares
 

 
 

 
 
 
 

 
 

Basic
33,062,297

 
32,879,381

 
33,047,166

 
33,021,865

 
32,779,234

Diluted
33,115,699

 
32,879,381

 
33,083,027

 
33,064,708

 
32,834,765



* General and administrative expenses for the three months ended March 31, 2017, 2016 and December 31, 2016 included non-cash stock-based compensation expense of $291,151, $277,907 and $275,184, respectively. For the nine months ended March 31, 2017 and 2016, non-cash stock compensation expense was $878,023 and $708,746, respectively.

** Restructuring charges include $59,339 of non-cash stock compensation expense for the nine months ended March 31, 2016.




Evolution Petroleum Corporation and Subsidiaries
Consolidated Condensed Balance Sheets
(Unaudited) 


 
March 31,
2017
 
June 30,
2016
Assets
 

 
 

Current assets
 

 
 

Cash and cash equivalents
$
20,220,249

 
$
34,077,060

Receivables
3,372,199

 
2,638,188

Deferred tax asset

 
105,321

Derivative assets, net
47,965

 
14,132

Prepaid expenses and other current assets
697,346

 
251,749

Total current assets
24,337,759

 
37,086,450

Oil and natural gas property and equipment, net (full-cost method of accounting)
62,771,528

 
59,970,463

Other property and equipment, net
45,194

 
28,649

Total property and equipment
62,816,722

 
59,999,112

Other assets
312,842

 
365,489

Total assets
$
87,467,323

 
$
97,451,051

Liabilities and Stockholders’ Equity
 

 
 

Current liabilities
 

 
 

Accounts payable
$
1,707,415

 
$
5,809,107

Accrued liabilities and other
694,051

 
2,097,951

State and federal income taxes payable
457,306

 
621,850

Total current liabilities
2,858,772

 
8,528,908

Long term liabilities
 

 
 

Deferred income taxes
14,814,714

 
11,840,693

Asset retirement obligations
811,226

 
760,300

Total liabilities
18,484,712

 
21,129,901

Commitments and contingencies (Note 15)
 
 
 
Stockholders’ equity
 

 
 

Preferred stock, par value $0.001; 5,000,000 shares authorized:8.5% Series A Cumulative Preferred Stock, 1,000,000 shares designated, 317,319 shares issued; no shares outstanding at March 31, 2017 as all shares were redeemed November 14, 2016 (Note 8); and 317,319 shares outstanding at June 30, 2016 with a liquidation preference of $7,932,975 ($25.00 per share)

 
317

Common stock; par value $0.001; 100,000,000 shares authorized: issued and outstanding 33,062,297 shares and 32,907,863 as of March 31, 2017 and June 30, 2016, respectively
33,062

 
32,907

Additional paid-in capital
40,659,387

 
47,171,563

Retained earnings
28,290,162

 
29,116,363

Total stockholders’ equity
68,982,611

 
76,321,150

Total liabilities and stockholders’ equity
$
87,467,323

 
$
97,451,051





Evolution Petroleum Corporation and Subsidiaries
Consolidated Condensed Statements of Cash Flows
(Unaudited)


 
Nine Months Ended 
 March 31,
 
2017
 
2016
Cash flows from operating activities
 

 
 

Net income attributable to the Company
$
6,543,552

 
$
3,785,892

Adjustments to reconcile net income to net cash provided by operating activities:
 

 
 

Depreciation, depletion and amortization
4,146,898

 
3,991,055

Impairments included in restructuring charge

 
569,228

Stock-based compensation
878,023

 
768,085

Accretion of discount on asset retirement obligations
39,892

 
34,555

Settlements of asset retirement obligations
(157,910
)
 

Deferred income taxes
3,079,342

 
(399,256
)
(Gain) loss on derivative instruments, net
(37,273
)
 
(4,099,759
)
Write-off of deferred loan costs

 
50,414

Changes in operating assets and liabilities:
 

 
 

Receivables
(723,161
)
 
1,178,053

Prepaid expenses and other current assets
(445,597
)
 
20,696

Accounts payable and accrued expenses
(1,808,566
)
 
(98,254
)
Income taxes payable
(164,544
)
 
(35,405
)
Net cash provided by operating activities
11,350,656

 
5,765,304

Cash flows from investing activities
 

 
 

Derivative settlement payments (paid) received
(318,618
)
 
3,513,285

Capital expenditures for oil and natural gas properties
(10,096,475
)
 
(12,191,121
)
Capital expenditures for other property and equipment
(32,260
)
 
(1,876
)
Other assets

 
(161,345
)
Net cash used in investing activities
(10,447,353
)
 
(8,841,057
)
Cash flows from financing activities
 

 
 

Proceeds from exercise of stock options

 
51,000

Cash dividends to preferred stockholders
(250,990
)
 
(505,726
)
Cash dividends to common stockholders
(6,116,323
)
 
(4,932,247
)
Common share repurchases, including shares surrendered for tax withholding
(459,858
)
 
(1,355,880
)
Tax benefits related to stock-based compensation

 
3,727,913

Redemption of preferred shares
(7,932,975
)
 

Other
32

 
(21,969
)
Net cash used in financing activities
(14,760,114
)
 
(3,036,909
)
Net decrease in cash and cash equivalents
(13,856,811
)
 
(6,112,662
)
Cash and cash equivalents, beginning of period
34,077,060

 
20,118,757

Cash and cash equivalents, end of period
$
20,220,249

 
$
14,006,095


Supplemental disclosures of cash flow information:
Nine Months Ended 
 March 31,
 
2017
 
2016
Income taxes paid
$
1,383,773

 
$
480,000

Louisiana carryback income tax refund and related interest received

 
1,556,999

Non-cash transactions:
 

 
 

Change in accounts payable used to acquire property and equipment
(3,181,640
)
 
(130,202
)
Deferred loan costs charged to oil and gas property costs

 
107,196

Oil and natural gas property costs incurred through recognition of asset retirement obligations
14,119

 

Settlement of accrued treasury stock purchases

 
(170,283
)
Royalty rights acquired through non-monetary exchange of patent and trademark assets
 
 
108,512




Supplemental Information on Oil and Natural Gas Operations (Unaudited)


 
Three Months Ended
 
 
 
 
 
March 31, 2017
 
Dec. 31, 2016
 
Variance
 
Variance %
Oil and gas production:
 
 
 
 
 
 
 
  Crude oil revenues
$
9,060,796

 
$
8,529,817

 
$
530,979

 
6.2
 %
  NGL revenues
464,641

 

 
464,641

 
n.m.

  Natural gas revenues

 

 

 
n.m.

  Total revenues
$
9,525,437

 
$
8,529,817

 
$
995,620

 
11.7
 %
 
 
 
 
 
 
 
 
  Crude oil volumes (Bbl)
183,811

 
182,815

 
996

 
0.5
 %
  NGL volumes (Bbl)
19,594

 

 
19,594

 
n.m.

  Natural gas volumes (Mcf)

 

 

 
n.m.

Equivalent volumes (BOE)
203,405

 
182,815

 
20,590

 
11.3
 %
 
 
 
 
 
 
 
 
  Crude oil (BOPD, net)
2,042

 
1,987

 
55

 
2.8
 %
  NGLs (BOEPD, net)
218

 

 
218

 
n.m.

  Natural gas (BOEPD, net)

 

 

 
n.m

 Equivalent volumes (BOEPD, net)
2,260

 
1,987

 
273

 
13.7
 %
 
 
 
 
 
 
 
 
  Crude oil price per Bbl
$
49.29

 
$
46.66

 
$
2.63

 
5.6
 %
  NGL price per Bbl
23.71

 

 
23.71

 
n.m.

  Natural gas price per Mcf

 

 

 
n.m

    Equivalent price per BOE
$
46.83

 
$
46.66

 
$
0.17

 
0.4
 %
 
 
 
 
 
 
 
 
CO2 costs
$
1,049,035

 
$
1,041,741

 
$
7,294

 
0.7
 %
All other lease operating expenses
1,762,223

 
1,250,680

 
511,543

 
40.9
 %
  Production costs
$
2,811,258

 
$
2,292,421

 
$
518,837

 
22.6
 %
  Production costs per BOE
$
13.82

 
$
12.54

 
$
1.28

 
10.2
 %
 
 
 
 
 
 
 
 
CO2 volumes (MMcf per day, gross)
66.3

 
67.0

 
(0.7
)
 
(1.0
)%
 
 
 
 
 
 
 
 
Oil and gas DD&A (a)
$
1,515,368

 
$
1,299,813

 
$
215,555

 
16.6
 %
Oil and gas DD&A per BOE
$
7.45

 
$
7.11

 
$
0.34

 
4.8
 %


n.m. Not meaningful.

(a) Excludes non-operating depreciation and amortization of $8,107 and $7,697 for the three months ended March 31, 2017 and December 31, 2016, respectively.



Supplemental Information on Oil and Natural Gas Operations (Unaudited)


 
Three Months Ended March 31,
 
 
 
 
 
2017
 
2016
 
Variance
 
Variance %
Oil and gas production:
 
 
 
 
 
 
 
  Crude oil revenues
$
9,060,796

 
$
5,005,955

 
$
4,054,841

 
81.0
 %
  NGL revenues
464,641

 
597

 
464,044

 
n.m.

  Natural gas revenues

 
183

 
(183
)
 
n.m.

  Total revenues
$
9,525,437

 
$
5,006,735

 
$
4,518,702

 
90.3
 %
 
 
 
 
 
 
 
 
  Crude oil volumes (Bbl)
183,811

 
166,881

 
16,930

 
10.1
 %
  NGL volumes (Bbl)
19,594

 
47

 
19,547

 
n.m.

  Natural gas volumes (Mcf)

 
145

 
(145
)
 
n.m.

Equivalent volumes (BOE)
203,405

 
166,952

 
36,453

 
21.8
 %
 
 
 
 
 
 
 
 
  Crude oil (BOPD, net)
2,042

 
1,834

 
208

 
11.3
 %
  NGLs (BOEPD, net)
218

 
1

 
217

 
n.m.

  Natural gas (BOEPD, net)

 

 

 
n.m.

 Equivalent volumes (BOEPD, net)
2,260

 
1,835

 
425

 
23.2
 %
 
 
 
 
 
 
 
 
  Crude oil price per Bbl
$
49.29

 
$
30.00

 
$
19.29

 
64.3
 %
  NGL price per Bbl
23.71

 
12.70

 
11.01

 
86.7
 %
  Natural gas price per Mcf

 
1.26

 
(1.26
)
 
n.m.

    Equivalent price per BOE
$
46.83

 
$
29.99

 
$
16.84

 
56.2
 %
 
 
 
 
 
 
 
 
CO2 costs
$
1,049,035

 
$
831,485

 
$
217,550

 
26.2
 %
All other lease operating expenses
1,762,223

 
1,360,732

 
401,491

 
29.5
 %
  Production costs
$
2,811,258

 
$
2,192,217

 
$
619,041

 
28.2
 %
  Production costs per BOE
$
13.82

 
$
13.13

 
$
0.69

 
5.3
 %
 
 
 
 
 
 
 
 
CO2 volumes (MMcf per day, gross)
66.3

 
73.1

 
(6.8
)
 
(9.3
)%
 
 
 
 
 
 
 
 
Oil and gas DD&A (a)
$
1,515,368

 
$
1,262,164

 
$
253,204

 
20.1
 %
Oil and gas DD&A per BOE
$
7.45

 
$
7.56

 
$
(0.11
)
 
(1.5
)%
 
 
 
 
 
 
 
 
Artificial lift technology services:
 
 
 
 
 
 
 
  Services revenues
$

 
$
100,000

 
$
(100,000
)
 
n.m.

Cost of service

 
10,933

 
(10,933
)
 
n.m.



n.m. Not meaningful.

(a) Excludes depreciation and amortization expense for artificial lift technology services and $8,107 and $6,636 of other depreciation and amortization expense for the three months ended March 31, 2017 and 2016, respectively.



Supplemental Information on Oil and Natural Gas Operations (Unaudited)


 
Nine Months Ended March 31,
 
 
 
 
 
2017
 
2016
 
Variance
 
Variance %
Oil and gas production:
 
 
 
 
 
 
 
  Crude oil revenues
$
25,184,468

 
$
18,897,572

 
$
6,286,896

 
33.3
 %
  NGL revenues
464,730

 
2,332

 
462,398

 
n.m.

  Natural gas revenues
(4
)
 
1,204

 
(1,208
)
 
n.m.

  Total revenues
$
25,649,194

 
$
18,901,108

 
$
6,748,086

 
35.7
 %
 
 
 
 
 
 
 
 
  Crude oil volumes (Bbl)
544,628

 
489,644

 
54,984

 
11.2
 %
  NGL volumes (Bbl)
19,598

 
171

 
19,427

 
n.m.

  Natural gas volumes (Mcf)
16

 
634

 
(618
)
 
n.m.

Equivalent volumes (BOE)
564,229

 
489,921

 
74,308

 
15.2
 %
 
 
 
 
 
 
 
 
  Crude oil (BOPD, net)
1,988

 
1,780

 
208

 
11.7
 %
  NGLs (BOEPD, net)
71

 
1

 
70

 
n.m.

  Natural gas (BOEPD, net)

 

 

 
n.m.

 Equivalent volumes (BOEPD, net)
2,059

 
1,781

 
278

 
15.6
 %
 
 
 
 
 
 
 
 
  Crude oil price per Bbl
$
46.24

 
$
38.59

 
$
7.65

 
19.8
 %
  NGL price per Bbl
23.71

 
13.64

 
10.07

 
73.8
 %
  Natural gas price per Mcf
(0.25
)
 
1.90

 
(2.15
)
 
n.m.

    Equivalent price per BOE
$
45.46

 
$
38.58

 
$
6.88

 
17.8
 %
 
 
 
 
 
 
 
 
CO2 costs
$
3,168,909

 
$
3,238,076

 
$
(69,167
)
 
(2.1
)%
All other lease operating expenses
4,279,411

 
3,792,461

 
486,950

 
12.8
 %
  Production costs
$
7,448,320

 
$
7,030,537

 
$
417,783

 
5.9
 %
  Production costs per BOE
$
13.20

 
$
14.35

 
$
(1.15
)
 
(8.0
)%
 
 
 
 
 
 
 
 
CO2 volumes (MMcf per day, gross)
69.0

 
78.7

 
(9.7
)
 
(12.3
)%
 
 
 
 
 
 
 
 
Oil and gas DD&A (a)
$
4,080,818

 
$
3,705,386

 
$
375,432

 
10.1
 %
Oil and gas DD&A per BOE
$
7.23

 
$
7.56

 
$
(0.33
)
 
(4.4
)%
 
 
 
 
 
 
 
 
Artificial lift technology services:
 
 
 
 
 
 
 
  Services revenues
$

 
$
207,960

 
$
(207,960
)
 
n.m.

Cost of service

 
70,932

 
(70,932
)
 
n.m.

Depreciation and amortization expense
$

 
$
238,475

 
$
(238,475
)
 
n.m.

 
 
 
 
 
 
 
 

n.m. Not meaningful.

(a) Excludes depreciation and amortization expense for artificial lift technology services and $23,606 and $14,783 of other depreciation and amortization expense for the nine months ended March 31, 2017 and 2016, respectively.

####