mcf_Form_8K

 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, DC 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):  August 9, 2018

 

CONTANGO OIL & GAS COMPANY

(Exact Name of Registrant as Specified in Charter)

 

 

 

 

 

 

 

 

Delaware

(State or Other Jurisdiction of Incorporation)

001-16317

 (Commission File Number)

95-4079863

(IRS Employer Identification No.)

 

 

717 Texas Ave., Suite 2900, Houston Texas 77002

(Address of Principal Executive Offices)

 

(713) 236-7400

(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):

 

 

[]  Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

[]  Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

[]  Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 14d-2(b))

[]  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

 

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.

 

 

 


 

 

Item 2.02        Results of Operations and Financial Condition.

 

On August 9, 2018, Contango Oil & Gas Company (the “Company”) issued a press release providing its financial results for the three and six months ended June 20, 2018. A copy of the press release is attached hereto as Exhibit 99.1.

As provided in General Instruction B.2. of Form 8-K, the information furnished pursuant to Item 2.02 in this report on Form 8-K (including the press release attached as Exhibit 99.1 incorporated by reference in this report) shall not be deemed to be “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, nor shall such information be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended (the “Securities Act”), or the Exchange Act, except as shall be expressly set forth by specific reference in such a filing.

Item 9.01        Financial Statements and Exhibits.

(d)                   Exhibits

Exhibit Number

 

Description

99.1

 

Press Release dated August 9, 2018

 

 

 

 

 


 

 

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.

 

17

 

 

 

 

CONTANGO OIL & GAS COMPANY

 

 

 

Date: August 9, 2018

 

/s/ E. JOSEPH GRADY

 

 

E. Joseph Grady

 

 

Senior Vice President and

 

 

Chief Financial and Accounting Officer

 


mcf_EX99_1

EXHIBIT 99.1

Contango oil & gas COMPANY

NEWS RELEASE

 

Contango Announces Second Quarter 2018 Financial Results and Provides Operational Update

 

AUGUST 9, 2018 – HOUSTON, TEXAS – Contango Oil & Gas Company (NYSE American: MCF) (“Contango” or the “Company”) announced today its financial results for the second quarter ended June 30, 2018 and provided an operational update. 

 

 

Summary Second Quarter Financial Results

 

Net loss for the three months ended June 30, 2018 was $7.2 million, or $0.29 per basic and diluted share, compared to a net loss of $6.0 million, or $0.24 per basic and diluted share for the same period last year. Operating earnings (i.e. revenues less expenses, before other income/expense) improved from a loss of $6.3 million in the 2017 quarter to a net loss of $4.1 million in the current quarter.  That improvement was overshadowed by a net loss on our outstanding derivatives during the current quarter compared to a gain in the 2017 quarter.  Average weighted shares outstanding were approximately 24.9 million and 24.7 million for the current and prior year quarters, respectively.    

 

The Company reported Adjusted EBITDAX, as defined below and on a recurring basis, of approximately $7.4 million for the three months ended June 30, 2018, compared to $10.2 million for the same period last year, a decrease attributable to lower revenues on lower production, and losses on our commodity price hedges in the current quarter compared to a gain in the prior year quarter.  Cash flow for the current quarter was $6.1 million, or $0.25 per share, compared to $9.3 million, or $0.38 per share for the prior year quarter. 

 

Revenues for the current quarter were approximately $18.4 million compared to $20.3 million for the 2017 quarter. We experienced a welcomed increase in crude oil and natural gas liquids prices during the quarter; however, a decline in natural gas prices, and lower production resulting from only one new well being added to production during the quarter and the Eugene Island 10 field being shut in for two weeks during the quarter for planned compression installation and maintenance, offset the benefit from liquids pricing.  Revenue from crude oil, however, increased to $9.6 million for the current quarter, compared to $6.5 million for the prior year quarter due to the increase in crude oil production resulting from our Southern Delaware drilling program and due to the higher crude oil prices.

 

Production for the second quarter of 2018 was approximately 3.9 Bcfe, or 42.4 Mmcfe per day, within our previously provided guidance, compared to 58.0 Mmcfe per day for the second quarter of 2017.  This expected year over year decline in equivalent production volumes is due to normal production declines, shutting in our offshore production for approximately two weeks to install compression and maintenance during the current quarter (loss of 4.2 Mmcfe/d) and the sale of our Eagle Ford Shale producing properties in Karnes County, Texas (loss of 0.7 Mmcfe/d).  Our production guidance for the third quarter of 2018 is expected to be between 43 to 48 Mmcfed.   

 

The weighted average equivalent sales price during the three months ended June 30, 2018 was $4.79 per Mcfe, compared to $3.84 per Mcfe for the same period last year, as a decline in natural gas prices was offset by increases of 39% and 38% in crude oil and natural gas liquids prices, respectively, compared to the prior year quarter, and due to the increase in the higher percentage of oil and liquids in the production mix. 


 

 

Operating expenses for the three months ended June 30, 2018 were approximately $6.5 million, or $1.68 per Mcfe, compared to $6.3 million, or $1.20 per Mcfe, for the same period last year. Included in operating expenses are direct lease operating expenses, transportation and processing costs, workover expenses and production and ad valorem taxes. Operating expenses exclusive of production and ad valorem taxes were approximately $5.6 million, or $1.46 per Mcfe, for the current quarter, which was comparable to the prior year quarter and below our previously provided guidance for the current quarter. Our guidance for operating expenses for the third quarter of 2018, exclusive of production and ad valorem taxes, is consistent with the second quarter at between $5.2 to $5.8 million.        

 

DD&A expense for the three months ended June 30, 2018 was $9.5 million, or $2.46 per Mcfe, compared to $12.7 million, or $2.41 per Mcfe, for the prior year quarter, a decrease primarily attributable to the lower production during the quarter. 

 

Impairment and abandonment expense of oil and gas properties was $0.8 million for the current quarter, as compared to $1.4 million for the prior year quarter.

 

Total G&A expenses, inclusive of stock compensation expense, for the three months ended June 30, 2018 were $5.4 million, compared to $5.8 million, for the prior year quarter.  Cash G&A expenses, i.e. G&A exclusive of stock compensation expense, was $3.8 million, or $0.98 per Mcfe for the current quarter, compared to $4.2 million, or $0.80 per Mcfe, respectively, for the prior year quarter.  For the third quarter of 2018, we have provided guidance of $4.25 to $4.75 million for cash general and administrative expenses.   

 

Loss from affiliates (i.e. Exaro Energy III) for the three months ended June 30, 2018 was approximately $0.5 million, compared to a gain of $0.2 million for the same period last year, a decrease attributable to the decline in natural gas prices.  

 

Gain from sale of assets for the three months ended June 30, 2018 was approximately $1.4 million, which related to the sale of our non-operated assets located in Starr County, Texas.

 

Loss on derivatives for the three months ended June 30, 2018 was approximately $2.6 million.  Of this amount, $0.8 million were realized losses while the remaining $1.8 million were non-cash, unrealized mark-to-market losses.  Gain on derivatives for the three months ended June 30, 2017 was approximately $1.5 million.  Of this amount, $0.4 million were realized gains while the remaining $1.1 million were unrealized mark-to-market gains.

 

Capital Costs and Drilling Activity Update

 

Capital costs incurred for the three months ended June 30, 2018 were approximately $9.5 million, including $8.1 million for the drilling and completion of wells in the Southern Delaware Basin in Pecos County, Texas.  

Our recent Southern Delaware Basin activity consists of the following:

Ragin Bull #2H

The Ragin Bull #2H (49% WI, 37% NRI), our second Wolfcamp B test, was spud in January 2018. Production began in April 2018 and achieved a 24-hour max IP rate of 805 Boed (68% oil) and a 30-day IP rate of 734 Boed (66% oil).  This well represents our fastest spud to total depth so far at 26.5 days. 

Sidewinder #1H / Gunner #3H

In July 2018, we brought two more wells on production which were drilled from a common pad, the Sidewinder #1H (49% WI, 37% NRI) targeting the Wolfcamp A formation and the Gunner #3H (47% WI,


 

35% NRI) targeting the Wolfcamp B. The Sidewinder was drilled to a TMD of 20,550 feet, including a 10,500 foot lateral, and had a maximum 30-day IP rate of 368 Boed (70% oil).  The Gunner #3H was drilled to a TMD of 20,167 feet, including a 10,067 foot lateral, and had a maximum 30-day IP rate of 773 Boed (78% oil).    

Fighting Ace #2H

On July 1, 2018, we spud the Fighting Ace #2H (50% WI, 38% NRI) targeting the Wolfcamp A which was drilled to a TMD of 20,560 feet, including a 10,598 foot lateral.  Completion operations on this well are expected to commence in mid-August, with initial production expected in mid-September.   

General Paxton #1H

On August 2, 2018, we spud the General Paxton #1H (50% WI, 38% NRI) in the southeast quadrant of our acreage position.  This well will target the Wolfcamp A formation and is expected to have a TMD of approximately 20,000 feet, including a lateral of approximately 10,000 feet.  From there, we expect to move the rig approximately five miles to the northwest and spud the River Rattler #4H.  After that, we will evaluate our strategy for the remainder of the year, given the dramatic increase in the Midland-Cushing oil differentials in the area.

Management Commentary

 

Allan D. Keel, the Company’s President and Chief Executive Officer said “We now have ten Southern Delaware Basin wells on production, with the eleventh (Fighting Ace #2H) expected to begin production in September.  The Permian Basin is one of the most prolific oil basins in the U.S. with hundreds of operators pushing U.S. oil production to record levels.  It’s no surprise that all this production has overwhelmed available pipeline capacity and caused oil prices in Midland to trade  at a double-digit discount to WTI in Cushing.  Once we finish drilling the River Rattler #4H, our plan is to evaluate this growing oil differential and decide the best strategy to take for the remainder of 2018 and beyond.”    

 

 

Derivative Instruments

 

We have the following financial derivative contracts in place at June 30, 2018:

 

 

 

 

 

 

 

 

 

 

 

Commodity

 

Period

 

Derivative

 

Volume/Month

 

Price/Unit

Natural Gas

 

July 2018

 

Swap

 

370,000 MMBtus

 

$

3.07 (1)

Natural Gas

 

Aug 2018 - Oct 2018

 

Swap

 

70,000 MMBtus

 

$

3.07 (1)

Natural Gas

 

Nov 2018 - Dec 2018

 

Swap

 

320,000 MMBtus

 

$

3.07 (1)

 

 

 

 

 

 

 

 

 

 

Oil

 

July 2018 - Oct 2018

 

Collar

 

20,000 Bbls

 

$

52.00 - 56.85 (2)

Oil

 

Nov 2018 - Dec 2018

 

Collar

 

15,000 Bbls

 

$

52.00 - 56.85 (2)

 

 

 

 

 

 

 

 

 

 

Oil

 

July 2018 - Dec 2018

 

Collar

 

2,000 Bbls

 

$

52.00 - 58.76 (3)

 

 

 

 

 

 

 

 

 

 

Oil

 

July 2018

 

Collar

 

6,000 Bbls

 

$

58.00 - 68.00 (2)

Oil

 

Nov 2018 - Dec 2018

 

Collar

 

5,000 Bbls

 

$

58.00 - 68.00 (2)

 

 

 

 

 

 

 

 

 

 

Oil

 

July 2018

 

Swap

 

6,000 Bbls

 

$

70.11 (3)

Oil

 

Aug 2018 - Oct 2018

 

Swap

 

3,000 Bbls

 

$

70.11 (3)

Oil

 

Nov 2018 - Dec 2018

 

Swap

 

6,000 Bbls

 

$

70.11 (3)

 

 

 

 

 

 

 

 

 

 

Oil

 

Jan 2019 - Dec 2019

 

Collar

 

4,000 Bbls

 

$

52.00 - 59.45 (3)


 

 

 

 

 

 

 

 

 

 

 

Oil

 

Jan 2019 - Dec 2019

 

Collar

 

7,000 Bbls

 

$

50.00 - 58.00 (2)

 

 

 

 

 

 

 

 

 

 

Oil

 

Jan 2019 - July 2019

 

Swap

 

6,000 Bbls

 

$

66.10 (3)

 

(1)

Based on Henry Hub NYMEX natural gas prices.

(2)

Based on Argus Louisiana Light Sweet crude oil prices.

(3)

Based on West Texas Intermediate crude oil prices.

 

 

 

 

Selected Financial and Operating Data

The following table reflects certain comparative financial and operating data for the three and six months ended June 30, 2018 and 2017:    

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

 

Six months ended

 

 

June 30, 

 

June 30, 

 

 

2018

 

2017

 

%

 

2018

 

2017

 

%

Offshore Volumes Sold:

    

 

 

    

 

 

    

 

 

 

 

    

 

 

    

 

Oil and condensate (Mbbls)

 

 

18

 

 

33

 

-45%

 

 

37

 

 

55

 

-33%

Natural gas (Mmcf)

 

 

1,695

 

 

2,908

 

-42%

 

 

3,991

 

 

5,916

 

-33%

Natural gas liquids (Mbbls)

 

 

59

 

 

83

 

-29%

 

 

137

 

 

167

 

-18%

Natural gas equivalents (Mmcfe)

 

 

2,156

 

 

3,602

 

-40%

 

 

5,033

 

 

7,248

 

-31%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Onshore Volumes Sold:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate (Mbbls)

 

 

133

 

 

109

 

22%

 

 

255

 

 

201

 

27%

Natural gas (Mmcf)

 

 

584

 

 

699

 

-16%

 

 

1,201

 

 

1,419

 

-15%

Natural gas liquids (Mbbls)

 

 

52

 

 

53

 

-2%

 

 

99

 

 

97

 

2%

Natural gas equivalents (Mmcfe)

 

 

1,698

 

 

1,675

 

1%

 

 

3,325

 

 

3,209

 

4%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Volumes Sold:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate (Mbbls)

 

 

151

 

 

142

 

6%

 

 

292

 

 

256

 

14%

Natural gas (Mmcf)

 

 

2,279

 

 

3,607

 

-37%

 

 

5,192

 

 

7,335

 

-29%

Natural gas liquids (Mbbls)

 

 

111

 

 

136

 

-18%

 

 

236

 

 

264

 

-11%

Natural gas equivalents (Mmcfe)

 

 

3,854

 

 

5,277

 

-27%

 

 

8,358

 

 

10,457

 

-20%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Daily Sales Volumes:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate (Mbbls)

 

 

1.7

 

 

1.6

 

6%

 

 

1.6

 

 

1.4

 

14%

Natural gas (Mmcf)

 

 

25.0

 

 

39.6

 

-37%

 

 

28.7

 

 

40.5

 

-29%

Natural gas liquids (Mbbls)

 

 

1.2

 

 

1.5

 

-18%

 

 

1.3

 

 

1.5

 

-11%

Natural gas equivalents (Mmcfe)

 

 

42.4

 

 

58.0

 

-27%

 

 

46.2

 

 

57.8

 

-20%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average sales prices:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate (per Bbl)

 

$

63.53

 

$

45.61

 

39%

 

$

63.16

 

$

46.99

 

34%

Natural gas (per Mcf)

 

$

2.57

 

$

3.09

 

-17%

 

$

2.78

 

$

3.04

 

-9%

Natural gas liquids (per Bbl)

 

$

26.84

 

$

19.50

 

38%

 

$

25.32

 

$

20.40

 

24%

Total (per Mcfe)

 

$

4.79

 

$

3.84

 

25%

 

$

4.65

 

$

3.80

 

22%

 

 

 

 

 

 

 


 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

 

Six Months Ended

 

 

June 30, 

 

June 30, 

 

 

2018

 

2017

 

%

   

2018

 

2017

 

%

Offshore Selected Costs ($ per Mcfe)

    

 

 

    

 

 

    

 

 

 

 

    

 

 

    

 

Lease operating expenses (1)

 

$

0.97

 

$

0.66

 

47%

 

$

0.88

 

$

0.71

 

24%

Production and ad valorem taxes

 

$

0.08

 

$

0.06

 

33%

 

$

0.07

 

$

0.06

 

17%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Onshore Selected Costs ($ per Mcfe)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Lease operating expenses (1)

 

$

2.09

 

$

1.94

 

8%

 

$

2.21

 

$

2.07

 

7%

Production and ad valorem taxes

 

$

0.39

 

$

0.29

 

34%

 

$

0.38

 

$

0.29

 

31%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average Selected Costs ($ per Mcfe)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Lease operating expenses (1)

 

$

1.46

 

$

1.07

 

36%

 

$

1.41

 

$

1.13

 

25%

Production and ad valorem taxes

 

$

0.22

 

$

0.13

 

69%

 

$

0.19

 

$

0.13

 

46%

General and administrative expense (cash)

 

$

0.98

 

$

0.80

 

23%

 

$

1.09

 

$

0.89

 

22%

Interest expense

 

$

0.33

 

$

0.18

 

83%

 

$

0.32

 

$

0.16

 

100%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Adjusted EBITDAX (2) (thousands)

 

$

7,401

 

$

10,231

 

 

 

$

15,745

 

$

17,385

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted Average Shares Outstanding (thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

 

24,933

 

 

24,671

 

 

 

 

24,863

 

 

24,639

 

 

Diluted

 

 

24,933

 

 

24,671

 

 

 

 

24,863

 

 

24,639

 

 


(1)

LOE includes transportation and workover expenses.

(2)

Adjusted EBITDAX is a non-GAAP financial measure. See below for reconciliation to net income.

 


 

CONTANGO OIL & GAS COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)

 

 

 

 

 

 

 

 

 

 

June 30, 

 

December 31, 

 

    

2018

    

2017

ASSETS

 

(unaudited)

Cash and cash equivalents

 

$

 —

 

$

 —

Accounts receivable, net

 

 

10,927

 

 

13,059

Other current assets

 

 

1,701

 

 

2,714

Net property and equipment

 

 

339,953

 

 

345,957

Investment in affiliates and other non-current assets

 

 

19,867

 

 

19,723

 

 

 

 

 

 

 

TOTAL ASSETS

 

$

372,448

 

$

381,453

 

 

 

 

 

 

 

LIABILITIES AND SHAREHOLDERS' EQUITY

 

 

 

 

 

 

Accounts payable and accrued liabilities

 

 

42,111

 

 

46,755

Other current liabilities

 

 

4,160

 

 

3,782

Long-term debt

 

 

80,827

 

 

85,380

Asset retirement obligations

 

 

19,722

 

 

20,388

Other non-current liabilities

 

 

4,456

 

 

548

Total shareholders’ equity

 

 

221,172

 

 

224,600

 

 

 

 

 

 

 

TOTAL LIABILITIES & SHAREHOLDERS’ EQUITY

 

$

372,448

 

$

381,453

 

 

 

 

 

 

 


 

CONTANGO OIL & GAS COMPANY

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

 

Six Months Ended

 

 

June 30, 

 

June 30, 

 

    

2018

    

2017

    

2018

    

2017

 

 

(unaudited)

REVENUES

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate sales

 

$

9,607

 

$

6,483

 

$

18,418

 

$

12,025

Natural gas sales

 

 

5,848

 

 

11,135

 

 

14,457

 

 

22,275

Natural gas liquids sales

 

 

2,993

 

 

2,658

 

 

6,010

 

 

5,400

Total revenues

 

 

18,448

 

 

20,276

 

 

38,885

 

 

39,700

 

 

 

 

 

 

 

 

 

 

 

 

 

EXPENSES

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses

 

 

6,478

 

 

6,329

 

 

13,405

 

 

13,162

Exploration expenses

 

 

394

 

 

284

 

 

863

 

 

375

Depreciation, depletion and amortization

 

 

9,498

 

 

12,714

 

 

19,983

 

 

24,485

Impairment and abandonment of oil and gas properties

 

 

777

 

 

1,401

 

 

4,104

 

 

1,431

General and administrative expenses

 

 

5,354

 

 

5,833

 

 

12,080

 

 

12,429

Total expenses

 

 

22,501

 

 

26,561

 

 

50,435

 

 

51,882

 

 

 

 

 

 

 

 

 

 

 

 

 

OTHER INCOME (EXPENSE)

 

 

 

 

 

 

 

 

 

 

 

 

Gain (loss) from investment in affiliates, net of income taxes

 

 

(475)

 

 

166

 

 

232

 

 

1,950

Gain (loss) from sale of assets

 

 

1,370

 

 

(420)

 

 

10,817

 

 

2,520

Interest expense

 

 

(1,262)

 

 

(925)

 

 

(2,671)

 

 

(1,684)

Gain (loss) on derivatives, net

 

 

(2,610)

 

 

1,487

 

 

(3,642)

 

 

4,583

Other income (expense)

 

 

 3

 

 

61

 

 

882

 

 

(27)

Total other income (expense)

 

 

(2,974)

 

 

369

 

 

5,618

 

 

7,342

 

 

 

 

 

 

 

 

 

 

 

 

 

NET LOSS BEFORE INCOME TAXES

 

 

(7,027)

 

 

(5,916)

 

 

(5,932)

 

 

(4,840)

 

 

 

 

 

 

 

 

 

 

 

 

 

Income tax provision

 

 

(151)

 

 

(118)

 

 

(309)

 

 

(309)

 

 

 

 

 

 

 

 

 

 

 

 

 

NET LOSS

 

$

(7,178)

 

$

(6,034)

 

$

(6,241)

 

$

(5,149)

 


 

Non-GAAP Financial Measures

 

EBITDAX represents net income (loss) before interest expense, taxes, and depreciation, depletion and amortization, and oil & gas expenses.  Adjusted EBITDAX represents EBITDAX as further adjusted to reflect the items set forth in the table below, all of which will be required in determining our compliance with financial covenants under our credit facility. 

 

We have included EBITDAX and Adjusted EBITDAX in this release to provide investors with a supplemental measure of our operating performance and information about the calculation of some of the financial covenants that are contained in our credit agreement.  We believe EBITDAX is an important supplemental measure of operating performance because it eliminates items that have less bearing on our operating performance and so highlights trends in our core business that may not otherwise be apparent when relying solely on GAAP financial measures.  We also believe that securities analysts, investors and other interested parties frequently use EBITDAX in the evaluation of companies, many of which present EBITDAX when reporting their results.  Adjusted EBITDAX is a material component of the covenants that are imposed on us by our credit agreement.  We are subject to financial covenant ratios that are calculated by reference to Adjusted EBITDAX.  Non-compliance with the financial covenants contained in our credit agreement could result in a default, an acceleration in the repayment of amounts outstanding and a termination of lending commitments.  Our management and external users of our financial statements, such as investors, commercial banks, research analysts and others, also use EBITDAX and Adjusted EBITDAX to assess:

 

·

the financial performance of our assets without regard to financing methods, capital structure or historical cost basis;

 

·

the ability of our assets to generate cash sufficient to pay interest costs and support our indebtedness;

 

·

our operating performance and return on capital as compared to those of other companies in our industry, without regard to financing or capital structure; and

 

·

the feasibility of acquisitions and capital expenditure projects and the overall rates of return on alternative investment opportunities.

 

EBITDAX and Adjusted EBITDAX are not presentations made in accordance with generally accepted accounting principles, or GAAP.  As discussed above, we believe that the presentation of EBITDAX and Adjusted EBITDAX in this release is appropriate.  However, when evaluating our results, you should not consider EBITDAX and Adjusted EBITDAX in isolation of, or as a substitute for, measures of our financial performance as determined in accordance with GAAP, such as net income (loss).  EBITDAX and Adjusted EBITDAX have material limitations as performance measures because they exclude items that are necessary elements of our costs and operations.  Because other companies may calculate EBITDAX and Adjusted EBITDAX differently than we do, EBITDAX may not be, and Adjusted EBITDAX as presented in this release is not, comparable to similarly-titled measures reported by other companies.

 


 

The following table reconciles net income to EBITDAX and Adjusted EBITDAX for the periods presented:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

 

Six Months Ended

 

 

June 30, 

 

June 30, 

 

    

2018

    

2017

    

2018

    

2017

 

 

(in thousands)

Net loss

 

$

(7,178)

 

$

(6,034)

 

$

(6,241)

 

$

(5,149)

Interest expense

 

 

1,262

 

 

925

 

 

2,671

 

 

1,684

Income tax provision

 

 

151

 

 

118

 

 

309

 

 

309

Depreciation, depletion and amortization

 

 

9,498

 

 

12,714

 

 

19,983

 

 

24,485

Exploration expense

 

 

394

 

 

284

 

 

863

 

 

375

EBITDAX

 

$

4,127

 

$

8,007

 

$

17,585

 

$

21,704

 

 

 

 

 

 

 

 

 

 

 

 

 

Unrealized loss (gain) on derivative instruments

 

$

1,792

 

$

(1,052)

 

$

2,311

 

$

(4,327)

Non-cash stock-based compensation charges

 

 

1,584

 

 

1,622

 

 

3,008

 

 

3,078

Impairment of oil and gas properties

 

 

793

 

 

1,400

 

 

3,890

 

 

1,400

Loss (gain) on sale of assets and investment in affiliates

 

 

(895)

 

 

254

 

 

(11,049)

 

 

(4,470)

Adjusted EBITDAX

 

$

7,401

 

$

10,231

 

$

15,745

 

$

17,385

 

 

Guidance for Third Quarter 2018

The Company is providing the following guidance for the third calendar quarter of 2018.

 

 

 

 

Production

    

43,000 - 48,000 Mcfe per day

 

 

 

LOE (including transportation and workovers)

 

$5.2 million - $5.8 million

 

 

 

Production and ad valorem taxes (% of Revenue)

 

3.75% - 4.25%

 

 

 

Cash G&A

 

$4.25 million - $4.75 million

 

 

 

DD&A Rate

 

$2.30 - $2.55

 

 

Teleconference Call

 

Contango management will hold a conference call to discuss the information described in this press release on Thursday, August 9, 2018 at 8:00am Central Daylight Time.  Those interested in participating in the earnings conference call may do so by calling the following phone number: 1-800-458-4148, (International 1-323-794-2597) and entering participation code 6006207.  A replay of the call will be available from Thursday, August 9, 2018 at 11:00am CDT through Wednesday, August 15, 2018 at 11:00am CDT by clicking in the audio replay link here and entering participation code 6006207.

 

Contango Oil & Gas Company is a Houston, Texas based, independent oil and natural gas company whose business is to maximize production and cash flow from its offshore properties in the shallow waters of the Gulf of Mexico and onshore properties in Texas and Wyoming and to use that cash flow to explore, develop, exploit, increase production from and acquire crude oil and natural gas properties in West Texas, the Texas Gulf Coast and the Rocky Mountain regions of the United States. Additional information is available on the Company's website at http://contango.com.

 

This press release contains forward-looking statements regarding Contango that are intended to be covered by the safe harbor "forward-looking statements" provided by the Private Securities Litigation Reform Act of 1995, based on Contango’s current expectations and includes statements regarding acquisitions and divestitures, estimates of future production, future results of operations, quality and nature of the asset base,


 

the assumptions upon which estimates are based and other expectations, beliefs, plans, objectives, assumptions, strategies or statements about future events or performance (often, but not always, using words such as "expects", “projects”, "anticipates", "plans", "estimates", "potential", "possible", "probable", or "intends", or stating that certain actions, events or results "may", "will", "should", or "could" be taken, occur or be achieved). Statements concerning oil and gas reserves also may be deemed to be forward looking statements in that they reflect estimates based on certain assumptions that the resources involved can be economically exploited. Forward-looking statements are based on current expectations, estimates and projections that involve a number of risks and uncertainties, which could cause actual results to differ materially from those, reflected in the statements. These risks include, but are not limited to: the risks of the oil and gas industry (for example, operational risks in exploring for, developing and producing crude oil and natural gas; risks and uncertainties involving geology of oil and gas deposits; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to future production, costs and expenses; potential delays or changes in plans with respect to exploration or development projects or capital expenditures; health, safety and environmental risks and risks related to weather such as hurricanes and other natural disasters); uncertainties as to the availability and cost of financing; fluctuations in oil and gas prices; risks associated with derivative positions; inability to realize expected value from acquisitions, inability of our management team to execute its plans to meet its goals, shortages of drilling equipment, oil field personnel and services, unavailability of gathering systems, pipelines and processing facilities and the possibility that government policies may change or governmental approvals may be delayed or withheld. Additional information on these and other factors which could affect Contango’s operations or financial results are included in Contango’s other reports on file with the Securities and Exchange Commission.  Investors are cautioned that any forward-looking statements are not guarantees of future performance and actual results or developments may differ materially from the projections in the forward-looking statements. Forward-looking statements are based on the estimates and opinions of management at the time the statements are made. Contango does not assume any obligation to update forward-looking statements should circumstances or management's estimates or opinions change. Initial production rates are subject to decline over time and should not be regarded as reflective of sustained production levels.

 

 

 

Contact:

 

Contango Oil & Gas Company

 

E. Joseph Grady – 713-236-7400

Sergio Castro – 713-236-7400

Senior Vice President and Chief Financial Officer

Vice President and Treasurer