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):  March 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 March 9, 2018, Contango Oil & Gas Company (the “Company”) issued a press release providing its financial results for the fourth quarter and full year ended December 31, 2017. 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 March 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: March 9, 2018

 

/s/ E. JOSEPH GRADY

 

 

E. Joseph Grady

 

 

Senior Vice President and

 

 

Chief Financial Officer

 


mcf_EX99_1

EXHIBIT 99.1

Contango oil & gas COMPANY

NEWS RELEASE

 

Contango Announces Fourth Quarter and Year Ended 2017 Financial Results

 

MARCH 9, 2018 – HOUSTON, TEXAS – Contango Oil & Gas Company (NYSE MKT: MCF) (“Contango” or the “Company”) announced today its financial results for the fourth quarter and year ended December 31, 2017. 

 

Fourth Quarter 2017 Highlights

 

·

Production of 4.8 Bcfe for the quarter (51.8 Mmcfed, 32% liquids); within guidance, despite late December weather related shut-ins

 

·

Adjusted EBITDAX of $10.2 million for the quarter

 

·

Brought one Southern Delaware Basin well on production while spudding two additional wells.  So far in 2018 we have completed one well, are completing another well, and have spud and reached total depth on another well

 

·

25% increase in year-end reserves, an increase of 37.5 Bcfe

 

·

55% increase in SEC PV-10 value of year-end reserves, an increase of $91.1 million

 

·

Increased commodity price hedge protection to approximately 28% of forecasted PDP gas production and 69% of forecasted PDP oil production for 2018, and to 38% of forecasted PDP oil production for 2019

 

Summary Fourth Quarter Financial Results

 

Net loss for the three months ended December 31, 2017 was $5.6 million, or $(0.23) per basic and diluted share, compared to a net loss of $16.8 million, or $(0.69) per basic and diluted share, for the same period last year. Last year’s quarter was negatively impacted by a commodity price driven impairment charge of $6.3 million compared to a current quarter impairment charge of $0.4 million. The impairment charge for the current quarter was related to the partial impairment of an unused offshore platform in onshore storage and impairment of our Tuscaloosa Marine Shale properties, while the impairment for the prior year quarter was related to non-core undeveloped acreage that we were not likely to drill prior to expiration. Average weighted shares outstanding were approximately 24.8 million and 24.6 million for the current and prior year quarters, respectively. 

 

The Company reported Adjusted EBITDAX, as defined below, of approximately $10.2 million for the three months ended December 31, 2017, compared to $8.2 million for the same period last year. The improvement was attributable to $1.7 million more in realized proceeds from derivatives and $1.9 million less in cash G&A costs, offset in part by a $1.6 million decrease in revenues from lower production. 

 

Revenues for the three months ended December 31, 2017 were approximately $20 million compared to $21.7 million for the same period last year, a decrease attributable to lower production during the current quarter


 

and a 4% decrease in natural gas prices, partially offset by a 20% and 38% increase in crude oil and natural gas liquids prices, respectively.

 

As previously reported, production for the fourth quarter of 2017 was approximately 4.8 Bcfe, or 51.8 Mmcfe per day, compared to 64.3 Mmcfe per day for the fourth quarter of 2016, and within our previously provided guidance.  This expected decrease in production can be attributed to the addition of only five new producing wells since the initiation of our drilling program in the Southern Delaware Basin beginning in late 2016. We also experienced cold weather shut-ins in some of our West Texas properties during the month of December. Crude oil and natural gas liquids production during the fourth quarter of 2017 was approximately 2,700 barrels per day, or 31.5% of total production, compared to approximately 3,080 barrels per day, or 28.8% of total production, in the fourth quarter of 2016, a decline related to the slower than planned pace of bringing on new production in our Southern Delaware Basin program.  Our first quarter 2018 production guidance is 50 – 55 Mmcfed, though we expect to commence production on two new wells in March and April. 

 

The weighted average equivalent sales price during the three months ended December 31, 2017 was $4.20 per Mcfe, compared to $3.66 per Mcfe for the same period last year.  As previously noted, stronger prices for crude oil and natural gas liquids, and a higher percentage of liquids in the production mix, contributed to the weighted average increase.

 

Operating expenses for the three months ended December 31, 2017 were approximately $7.0 million, or $1.47 per Mcfe, compared to $6.3 million, or $1.07 per Mcfe, for the same period last year.  Included in operating expenses are lease operating expenses, transportation and processing costs, workover expenses and production and ad valorem taxes. Operating expenses exclusive of production and ad valorem taxes for the three months ended December 31, 2017 were approximately $6.4 million, or $1.34 per Mcfe, compared to approximately $5.9 million, or $1.00 per Mcfe, for the same period last year, and below our previously provided guidance for the quarter.  The increase is due to accruing higher minimum volume charges for an ongoing throughput deficiency in our Madisonville Field.    

 

DD&A expense for the three months ended December 31, 2017 was $11.5 million, or $2.42 per Mcfe, compared to $13.7 million, or $2.32 per Mcfe, for the same period last year, a decrease primarily attributable to lower production during the quarter. 

Impairment and abandonment expense from oil and gas properties was $0.9 million for the three months ended December 31, 2017.  Of this amount, $0.1 million related to the partial impairment of an unused offshore platform in onshore storage and $0.3 million related to revised estimated reserves for our Tuscaloosa Marine Shale properties.   For the same period last year, impairment and abandonment expense from oil and gas properties was $6.3 million which related to the impairment of undeveloped leases in non-core areas.

 

G&A expenses for the three months ended December 31, 2017 were $5.5 million, or $1.16 per Mcfe, compared to $8.0 million, or $1.36 per Mcfe, for the prior year quarter.  G&A expenses for the current and prior year quarters include $1.5 million and $2.1 million, respectively, in non-cash stock compensation expense. Other items contributing to the decrease in G&A costs for the current quarter were lower bonus accruals for the 2017 performance period and lower insurance and office costs for the current quarter. For the first quarter of 2018, we have provided guidance of $4.5 million to $5.0 million for general and administrative expenses, exclusive of non-cash stock compensation (“Cash G&A”). 

 

Gain from affiliates for the three months ended December 31, 2017 was approximately $0.2 million, compared to a loss from affiliates of $0.3 million for the same period last year, both associated with our 37% equity interest in Exaro Energy III.  

 

 

 


 

 

2018 Capital Program & Liquidity

 

Capital costs incurred for the three months ended December 31, 2017 were approximately $13.6 million, which was primarily related to our Southern Delaware Basin acreage in Pecos County, Texas.  As previously reported, we have budgeted to invest approximately $52 million in 2018 to continue to develop that area with a one rig program.   We expect that program to be funded by internally generated cash flow, proceeds from non-core asset sales and/or temporary borrowings under our revolving credit facility.  We will continue to monitor commodity prices, drilling results and service/supply costs during the year, and if deemed appropriate, may make adjustments to our drilling strategy for the remainder of the year

 

As of December 31, 2017, we had approximately $85.4 million of debt outstanding under our credit facility, provides for a borrowing base of $115 million through May 1, 2018. 

 

2017 Year End Reserves

 

As previously disclosed in our March 5, 2018 release on reserves and production, proved reserves at December 31, 2017, as estimated by William M. Cobb & Associates, Inc. and Netherland, Sewell & Associates, Inc., Contango’s independent petroleum engineering firms, in accordance with reserve reporting guidelines mandated by the Securities and Exchange Commission (“SEC”), were 189.3 Bcfe, a 25% increase over our proved reserves as of December 31, 2016, consisting of 105.1 billion cubic feet of natural gas, 3.4 million barrels of crude oil, and 4.4 million barrels of natural gas liquids.  As of December 31, 2017, the SEC PV-10 value of our proved reserves was approximately $257.3 million, compared to $166.2 million as of December 31, 2016.  As of December 31, 2017, 48% of our proved reserves were natural gas and 65% were proved developed. 

 

The following table summarizes Contango’s total proved reserves as of December 31, 2017 (1)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Present Value

 

 

OIL

 

NGL

 

Gas

 

Total

 

Discounted

Category

 

(MBbl)

 

(MBbl)

 

(Mmcf)

 

(Mmcfe)

 

at 10% ($000)

Developed

 

3,364

 

3,596

 

82,133

 

123,895

 

200,723

Undeveloped

 

7,285

 

2,011

 

9,586

 

 65,359

 

 56,560

Total Proved

 

10,649

 

5,607

 

91,719

 

189,254

 

257,283

 

(1)

These estimates do not include net reserves of approximately 30.7 Bcfe (PV-10 of approximately $24.4 million attributable to our 37% equity ownership investment in Exaro as of December 31, 2017.

 

 

Derivative Instruments

As previously disclosed in our March 5, 2018 operations update, we took advantage of rising commodity prices and added additional minimum price protection for our forecasted monthly production volumes and now have the following financial derivative contracts in place with members of our bank group.  These contracts represent approximately 28% of our currently forecasted 2018 PDP natural gas production; 69% of our currently forecasted 2018 PDP crude oil production and 38% of our currently forecasted 2019 PDP oil production.

 

\


 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Commodity

Period

Derivative

Volume/Month

        Price/Unit

Natural Gas

Jan – July 2018

Swap

370,000 MMbtu

$3.07 (1)

 

Aug – Oct 2018

Swap

70,000 MMbtu

$3.07 (1)

 

Nov – Dec 2018

Swap

320,000 MMbtu

$3.07 (1)

 

 

 

 

 

Crude Oil

Jan - Jun 2018

Swap

20,000 Bbls

$56.40 (2)

 

Jul – Oct 2018

Collar

20,000 Bbls

$52.00 x $56.85 (2)

 

Nov – Dec 2018

Collar

15,000 Bbls

$52.00 x $56.85 (2)

 

Jan – Dec 2018

Collar

2,000 Bbls

$52.00 x $58.76 (3)

 

Jan – Jul 2018

Collar

6,000 Bbls

$58.00 x $68.00 (2)

 

Nov – Dec 2018

Collar

5,000 Bbls

$58.00 x $68.00 (2)

 

Jan – Dec 2019

Collar

7,000 Bbls

$50.00 x $58.00 (2)

 

Jan – Dec 2019

Collar

4,000 Bbls

$52.00 x $59.45 (3)

 

 

 

 

 

 

 

 

 

 

 

(1)

Based on Henry Hub NYMEX natural gas prices

(2)

Based on Argus/LLS oil prices

(3)

Based on West Texas Intermediate oil prices

 

 

 

 

 


 

Selected Financial and Operating Data

 

The following table reflects certain comparative financial and operating data for the three and twelve months ended December 31, 2017 and 2016:    

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

 

Year ended

 

 

December 31, 

 

December 31, 

 

 

2017

 

2016

 

%

 

2017

 

2016

 

%

Offshore Volumes Sold:

    

 

 

    

 

 

    

 

 

 

 

    

 

 

    

 

Oil and condensate (Mbbls)

 

 

21

 

 

31

 

-32%

 

 

99

 

 

137

 

-28%

Natural gas (Mmcf)

 

 

2,571

 

 

3,369

 

-24%

 

 

11,189

 

 

14,211

 

-21%

Natural gas liquids (Mbbls)

 

 

76

 

 

97

 

-22%

 

 

330

 

 

420

 

-21%

Natural gas equivalents (Mmcfe)

 

 

3,154

 

 

4,137

 

-24%

 

 

13,762

 

 

17,552

 

-22%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Onshore Volumes Sold:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate (Mbbls)

 

 

109

 

 

96

 

14%

 

 

419

 

 

460

 

-9%

Natural gas (Mmcf)

 

 

689

 

 

846

 

-19%

 

 

2,721

 

 

3,892

 

-30%

Natural gas liquids (Mbbls)

 

 

44

 

 

60

 

-27%

 

 

187

 

 

296

 

-37%

Natural gas equivalents (Mmcfe)

 

 

1,610

 

 

1,779

 

-9%

 

 

6,361

 

 

8,430

 

-25%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Total Volumes Sold:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate (Mbbls)

 

 

130

 

 

127

 

2%

 

 

518

 

 

597

 

-13%

Natural gas (Mmcf)

 

 

3,260

 

 

4,215

 

-23%

 

 

13,910

 

 

18,103

 

-23%

Natural gas liquids (Mbbls)

 

 

120

 

 

157

 

-24%

 

 

517

 

 

716

 

-28%

Natural gas equivalents (Mmcfe)

 

 

4,764

 

 

5,916

 

-19%

 

 

20,123

 

 

25,982

 

-23%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Daily Sales Volumes:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate (Mbbls)

 

 

1.4

 

 

1.4

 

2%

 

 

1.4

 

 

1.6

 

-13%

Natural gas (Mmcf)

 

 

35.4

 

 

45.8

 

-23%

 

 

38.1

 

 

49.5

 

-23%

Natural gas liquids (Mbbls)

 

 

1.3

 

 

1.7

 

-24%

 

 

1.4

 

 

2.0

 

-28%

Natural gas equivalents (Mmcfe)

 

 

51.8

 

 

64.3

 

-19%

 

 

55.1

 

 

71.0

 

-23%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average sales prices:

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate (per Bbl)

 

$

55.30

 

$

46.08

 

20%

 

$

48.90

 

$

38.52

 

27%

Natural gas (per Mcf)

 

$

2.87

 

$

2.98

 

-4%

 

$

2.97

 

$

2.42

 

23%

Natural gas liquids (per Bbl)

 

$

28.59

 

$

20.76

 

38%

 

$

22.97

 

$

15.79

 

45%

Total (per Mcfe)

 

$

4.20

 

$

3.66

 

15%

 

$

3.90

 

$

3.01

 

30%

 

 

 

 

 

 

 


 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

 

Year Ended

 

 

December 31, 

 

December 31, 

 

 

2017

 

2016

 

%

   

2017

 

2016

 

%

Offshore Selected Costs ($ per Mcfe)

    

 

 

    

 

 

    

 

 

 

 

    

 

 

    

 

Lease operating expenses (1)

 

$

0.61

 

$

0.66

 

-8%

 

$

0.72

 

$

0.60

 

20%

Production and ad valorem taxes

 

$

0.06

 

$

0.05

 

20%

 

$

0.06

 

$

0.07

 

-14%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Onshore Selected Costs ($ per Mcfe)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Lease operating expenses (1)

 

$

2.78

 

$

1.77

 

57%

 

$

2.32

 

$

1.81

 

28%

Production and ad valorem taxes

 

$

0.25

 

$

0.13

 

92%

 

$

0.28

 

$

0.25

 

12%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Average Selected Costs ($ per Mcfe)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Lease operating expenses (1)

 

$

1.34

 

$

1.00

 

34%

 

$

1.22

 

$

1.00

 

22%

Production and ad valorem taxes

 

$

0.12

 

$

0.07

 

71%

 

$

0.13

 

$

0.13

 

0%

General and administrative expense (cash)

 

$

0.83

 

$

1.00

 

-17%

 

$

0.90

 

$

0.78

 

15%

Interest expense

 

$

0.27

 

$

0.13

 

108%

 

$

0.20

 

$

0.15

 

33%

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Adjusted EBITDAX (2) (thousands)

 

$

10,213

 

$

8,159

 

 

 

$

35,087

 

$

30,142

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Weighted Average Shares Outstanding (thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Basic

 

 

24,757

 

 

24,563

 

 

 

 

24,686

 

 

21,424

 

 

Diluted

 

 

24,757

 

 

24,563

 

 

 

 

24,686

 

 

21,424

 

 


(1)

LOE includes transportation and workover expenses.

(2)

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

 


 

CONTANGO OIL & GAS COMPANY

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)

 

 

 

 

 

 

 

 

 

 

December 31, 

 

December 31, 

 

    

2017

    

2016

ASSETS

 

(unaudited)

Cash and cash equivalents

 

$

 —

 

$

 —

Accounts receivable, net

 

 

13,059

 

 

16,727

Other current assets

 

 

2,714

 

 

2,327

Net property and equipment

 

 

345,957

 

 

340,382

Investment in affiliates and other non-current assets

 

 

19,723

 

 

17,078

 

 

 

 

 

 

 

TOTAL ASSETS

 

$

381,453

 

$

376,514

 

 

 

 

 

 

 

LIABILITIES AND SHAREHOLDERS' EQUITY

 

 

 

 

 

 

Accounts payable and accrued liabilities

 

 

46,755

 

 

55,135

Other current liabilities

 

 

3,782

 

 

7,754

Long-term debt

 

 

85,380

 

 

54,354

Asset retirement obligations

 

 

20,388

 

 

22,618

Other non-current liabilities

 

 

548

 

 

248

Total shareholders’ equity

 

 

224,600

 

 

236,405

 

 

 

 

 

 

 

TOTAL LIABILITIES & SHAREHOLDERS’ EQUITY

 

$

381,453

 

$

376,514

 

 

 

 

 

 

 


 

CONTANGO OIL & GAS COMPANY

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands)

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

 

Three Months Ended

 

Year Ended

 

 

December 31, 

 

December 31, 

 

    

2017

    

2016

    

2017

    

2016

 

 

(unaudited)

REVENUES

 

 

 

 

 

 

 

 

 

 

 

 

Oil and condensate sales

 

$

7,213

 

$

5,842

 

$

25,347

 

$

23,006

Natural gas sales

 

 

9,361

 

 

12,564

 

 

41,317

 

 

43,847

Natural gas liquids sales

 

 

3,441

 

 

3,257

 

 

11,881

 

 

11,330

Total revenues

 

 

20,015

 

 

21,663

 

 

78,545

 

 

78,183

 

 

 

 

 

 

 

 

 

 

 

 

 

EXPENSES

 

 

 

 

 

 

 

 

 

 

 

 

Operating expenses

 

 

6,980

 

 

6,329

 

 

27,183

 

 

29,111

Exploration expenses

 

 

416

 

 

728

 

 

1,106

 

 

1,816

Depreciation, depletion and amortization

 

 

11,537

 

 

13,737

 

 

47,215

 

 

63,323

Impairment and abandonment of oil and gas properties

 

 

880

 

 

6,304

 

 

2,395

 

 

10,572

General and administrative expenses

 

 

5,513

 

 

8,030

 

 

24,161

 

 

26,802

Total expenses

 

 

25,326

 

 

35,128

 

 

102,060

 

 

131,624

 

 

 

 

 

 

 

 

 

 

 

 

 

OTHER INCOME (EXPENSE)

 

 

 

 

 

 

 

 

 

 

 

 

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

 

 

222

 

 

(257)

 

 

2,697

 

 

1,545

Gain (loss) from sale of assets

 

 

(56)

 

 

(103)

 

 

2,280

 

 

(92)

Interest expense

 

 

(1,278)

 

 

(757)

 

 

(4,100)

 

 

(3,802)

Gain (loss) on derivatives, net

 

 

(1,249)

 

 

(2,368)

 

 

3,325

 

 

(1,632)

Other income (expense)

 

 

1,302

 

 

38

 

 

1,275

 

 

(265)

Total other income (expense)

 

 

(1,059)

 

 

(3,447)

 

 

5,477

 

 

(4,246)

 

 

 

 

 

 

 

 

 

 

 

 

 

NET LOSS BEFORE INCOME TAXES

 

 

(6,370)

 

 

(16,912)

 

 

(18,038)

 

 

(57,687)

 

 

 

 

 

 

 

 

 

 

 

 

 

Income tax benefit (provision)

 

 

792

 

 

68

 

 

395

 

 

(342)

 

 

 

 

 

 

 

 

 

 

 

 

 

NET LOSS

 

$

(5,578)

 

$

(16,844)

 

$

(17,643)

 

$

(58,029)

 


 

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

 

Year Ended

 

 

December 31, 

 

December 31, 

 

    

2017

    

2016

    

2017

    

2016

 

 

(in thousands)

Net loss

 

$

(5,578)

 

$

(16,844)

 

$

(17,643)

 

$

(58,029)

Interest expense

 

 

1,278

 

 

757

 

 

4,100

 

 

3,802

Income tax provision (benefit)

 

 

(792)

 

 

(68)

 

 

(395)

 

 

342

Depreciation, depletion and amortization

 

 

11,537

 

 

13,737

 

 

47,215

 

 

63,323

Exploration expense

 

 

416

 

 

728

 

 

1,106

 

 

1,816

EBITDAX

 

$

6,861

 

$

(1,690)

 

$

34,383

 

$

11,254

 

 

 

 

 

 

 

 

 

 

 

 

 

Unrealized loss (gain) on derivative instruments

 

$

1,593

 

$

1,046

 

$

(2,204)

 

$

3,446

Non-cash stock-based compensation charges

 

 

1,540

 

 

2,142

 

 

6,100

 

 

6,457

Impairment of oil and gas properties

 

 

385

 

 

6,301

 

 

1,785

 

 

10,438

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

 

 

(166)

 

 

360

 

 

(4,977)

 

 

(1,453)

Adjusted EBITDAX

 

$

10,213

 

$

8,159

 

$

35,087

 

$

30,142

 

 

 

Guidance for First Quarter 2018

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

 

 

 

 

Production

    

50,000 - 55,000 Mcfe per day

 

 

 

LOE (including transportation and workovers)

 

$6.4 million - $6.9 million

 

 

 

Production and ad valorem taxes (% of Revenue)

 

3.0 - 3.5%

 

 

 

Cash G&A

 

$4.5 million - $5.0 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 Friday, March 9, 2018 at 9:30am Central Daylight Time.  Those interested in participating in the earnings conference call may do so by calling 1-800-289-0517, (International 1-323-994-2083) and entering participation code 5264056.  A replay of the call will be available from Friday, March 9, 2018 at 12:30pm CDT through Friday, March 16, 2018 at 12:30pm CDT by clicking here.  

 

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