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Contango Announces First Quarter 2018 Financial Results and Provides Operational Update
First Quarter Highlights
- Sale of non-core
Eagle Ford Shale assets for$21 million
- Production of 4.5 Bcfe for the quarter, or 50.0 Mmcfed
- Net income of
$0.9 million for the quarter
- Adjusted EBITDAX, on a recurring basis, of
$8.3 million for the quarter
- Commenced production from two more
Pecos County wells in theSouthern Delaware Basin , and a third well in April
Summary First Quarter Financial Results
Net income for the three months ended
The Company reported Adjusted EBITDAX, as defined below and on a recurring basis, of approximately
Revenues for the current quarter were approximately
Production for the first quarter of 2018 was approximately 4.5 Bcfe, or 50.0 Mmcfe per day, within our previously provided guidance, compared to 57.6 Mmcfe per day for the first quarter of 2017. This expected year over year decline in equivalent production volumes is mitigated in part by the fact that the percentage of production from higher-value oil and natural gas liquids increased from 28% to 35%. As the year progresses, that percentage should continue to increase due to our oil-weighted drilling program. Crude oil and natural gas liquids production during the first quarter of 2018 was approximately 3,000 barrels per day, compared to approximately 2,700 barrels per day in the first quarter of 2017. Our production guidance for the second quarter of 2018 is expected to be between 41–46 Mmcfed, due to shutting in our offshore production for approximately two weeks for scheduled maintenance to install compression, normal production declines and the sale of our
The weighted average equivalent sales price during the three months ended
Operating expenses for the three months ended
DD&A expense for the three months ended
Impairment and abandonment expense of oil and gas properties was
Total G&A expenses, inclusive of stock compensation expense, for the three months ended
Gain from affiliates (i.e. Exaro Energy III) for the three months ended
Gain from sale of assets for the three months ended
2018 Capital Program
Capital costs incurred for the three months ended
As of
Drilling Activity Update
Our recent
River Rattler #1H
As previously reported, the River Rattler #1H (44% WI, 33% NRI), our first Wolfcamp B test, was spud in December 2017. Production began in March 2018 at an initial 24-hour max IP rate of 1,416 Boed (74% oil) and an initial 30-day rate of 1,225 Boed (74% oil), making it our best well to date from an IP perspective. We continue to identify cost efficiencies in our drilling efforts, as evidenced by the fact that the Ragin Bull #3H, which immediately preceded this well, and River Rattler #1H have taken only 27 days from spud to TMD.
Ragin Bull #2H
The Ragin Bull #2H (49% WI, 37% NRI), our second Wolfcamp B test, was spud in January 2018. Production began in
Sidewinder #1H / Gunner #3H
The Sidewinder #1H (49% WI, 37% NRI), the first of two wells to be drilled from a common pad, was spud in
For the remainder of the year, our capital expenditure budget calls for us to drill five to six more wells, with the next one being the Fighting Ace #2H. This well will target the Wolfcamp B formation and is expected to be spud in May 2018.
Management Commentary
Selected Financial and Operating Data
The following table reflects certain comparative financial and operating data for the three months ended
| Three Months Ended | ||||||||
| March 31, | ||||||||
| 2018 | 2017 | % | ||||||
| Offshore Volumes Sold: | ||||||||
| Oil and condensate (Mbbls) | 19 | 22 | -14% | |||||
| Natural gas (Mmcf) | 2,296 | 3,008 | -24% | |||||
| Natural gas liquids (Mbbls) | 78 | 84 | -7% | |||||
| Natural gas equivalents (Mmcfe) | 2,877 | 3,646 | -21% | |||||
| Onshore Volumes Sold: | ||||||||
| Oil and condensate (Mbbls) | 121 | 92 | 32% | |||||
| Natural gas (Mmcf) | 617 | 720 | -14% | |||||
| Natural gas liquids (Mbbls) | 47 | 44 | 7% | |||||
| Natural gas equivalents (Mmcfe) | 1,627 | 1,534 | 6% | |||||
| Total Volumes Sold: | ||||||||
| Oil and condensate (Mbbls) | 140 | 114 | 23% | |||||
| Natural gas (Mmcf) | 2,913 | 3,728 | -22% | |||||
| Natural gas liquids (Mbbls) | 125 | 128 | -2% | |||||
| Natural gas equivalents (Mmcfe) | 4,504 | 5,180 | -13% | |||||
| Daily Sales Volumes: | ||||||||
| Oil and condensate (Mbbls) | 1.6 | 1.3 | 23% | |||||
| Natural gas (Mmcf) | 32.4 | 41.4 | -22% | |||||
| Natural gas liquids (Mbbls) | 1.4 | 1.4 | -2% | |||||
| Natural gas equivalents (Mmcfe) | 50.0 | 57.6 | -13% | |||||
| Average sales prices: | ||||||||
| Oil and condensate (per Bbl) | $ | 62.76 | $ | 48.71 | 29% | |||
| Natural gas (per Mcf) | $ | 2.96 | $ | 2.99 | -1% | |||
| Natural gas liquids (per Bbl) | $ | 23.97 | $ | 21.36 | 12% | |||
| Total (per Mcfe) | $ | 4.53 | $ | 3.75 | 21% | |||
| Three Months Ended | ||||||||
| March 31, | ||||||||
| 2018 | 2017 | % | ||||||
| Offshore Selected Costs ($ per Mcfe) | ||||||||
| Lease operating expenses (1) | $ | 0.82 | $ | 0.93 | -12% | |||
| Production and ad valorem taxes | $ | 0.07 | $ | 0.13 | -46% | |||
| Onshore Selected Costs ($ per Mcfe) | ||||||||
| Lease operating expenses (1) | $ | 2.33 | $ | 1.81 | 29% | |||
| Production and ad valorem taxes | $ | 0.36 | $ | 0.13 | 177% | |||
| Average Selected Costs ($ per Mcfe) | ||||||||
| Lease operating expenses (1) | $ | 1.37 | $ | 1.19 | 15% | |||
| Production and ad valorem taxes | $ | 0.17 | $ | 0.13 | 31% | |||
| General and administrative expense (cash) | $ | 1.18 | $ | 0.99 | 19% | |||
| Interest expense | $ | 0.31 | $ | 0.15 | 107% | |||
| Adjusted EBITDAX (2) (thousands) | $ | 8,344 | $ | 7,154 | ||||
| Weighted Average Shares Outstanding (thousands) | ||||||||
| Basic | 24,793 | 24,607 | ||||||
| Diluted | 24,841 | 24,641 | ||||||
_______________________________
- LOE includes transportation and workover expenses.
- 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) | ||||||
| March 31, | December 31, | |||||
| 2018 | 2017 | |||||
| ASSETS | (unaudited) | |||||
| Cash and cash equivalents | $ | — | $ | — | ||
| Accounts receivable, net | 13,701 | 13,059 | ||||
| Other current assets | 1,688 | 2,714 | ||||
| Net property and equipment | 340,533 | 345,957 | ||||
| Investment in affiliates and other non-current assets | 20,638 | 19,723 | ||||
| TOTAL ASSETS | $ | 376,560 | $ | 381,453 | ||
| LIABILITIES AND SHAREHOLDERS' EQUITY | ||||||
| Accounts payable and accrued liabilities | 42,610 | 46,755 | ||||
| Other current liabilities | 3,639 | 3,782 | ||||
| Long-term debt | 78,660 | 85,380 | ||||
| Asset retirement obligations | 20,455 | 20,388 | ||||
| Other non-current liabilities | 4,306 | 548 | ||||
| Total shareholders’ equity | 226,890 | 224,600 | ||||
| TOTAL LIABILITIES & SHAREHOLDERS’ EQUITY | $ | 376,560 | $ | 381,453 | ||
| CONTANGO OIL & GAS COMPANY | ||||||||
| CONSOLIDATED STATEMENTS OF OPERATIONS | ||||||||
| (in thousands) | ||||||||
| Three Months Ended | ||||||||
| March 31, | ||||||||
| 2018 | 2017 | |||||||
| (unaudited) | ||||||||
| REVENUES | ||||||||
| Oil and condensate sales | $ | 8,811 | $ | 5,542 | ||||
| Natural gas sales | 8,609 | 11,140 | ||||||
| Natural gas liquids sales | 3,017 | 2,742 | ||||||
| Total revenues | 20,437 | 19,424 | ||||||
| EXPENSES | ||||||||
| Operating expenses | 6,927 | 6,833 | ||||||
| Exploration expenses | 469 | 91 | ||||||
| Depreciation, depletion and amortization | 10,485 | 11,771 | ||||||
| Impairment and abandonment of oil and gas properties | 3,327 | 30 | ||||||
| General and administrative expenses | 6,726 | 6,596 | ||||||
| Total expenses | 27,934 | 25,321 | ||||||
| OTHER INCOME (EXPENSE) | ||||||||
| Gain from investment in affiliates, net of income taxes | 707 | 1,784 | ||||||
| Gain from sale of assets | 9,447 | 2,940 | ||||||
| Interest expense | (1,409 | ) | (759 | ) | ||||
| Gain (loss) on derivatives, net | (1,032 | ) | 3,096 | |||||
| Other income (expense) | 879 | (88 | ) | |||||
| Total other income | 8,592 | 6,973 | ||||||
| NET INCOME BEFORE INCOME TAXES | 1,095 | 1,076 | ||||||
| Income tax provision | (158 | ) | (191 | ) | ||||
| NET INCOME | $ | 937 | $ | 885 | ||||
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 | ||||||||
| March 31, | ||||||||
| 2018 | 2017 | |||||||
| (in thousands) | ||||||||
| Net income | $ | 937 | $ | 885 | ||||
| Interest expense | 1,409 | 759 | ||||||
| Income tax provision | 158 | 191 | ||||||
| Depreciation, depletion and amortization | 10,485 | 11,771 | ||||||
| Exploration expense | 469 | 91 | ||||||
| EBITDAX | $ | 13,458 | $ | 13,697 | ||||
| Unrealized loss (gain) on derivative instruments | $ | 519 | $ | (3,275 | ) | |||
| Non-cash stock-based compensation charges | 1,424 | 1,456 | ||||||
| Impairment of oil and gas properties | 3,097 | — | ||||||
| Gain on sale of assets and investment in affiliates | (10,154 | ) | (4,724 | ) | ||||
| Adjusted EBITDAX | $ | 8,344 | $ | 7,154 | ||||
Guidance for Second Quarter 2018
The Company is providing the following guidance for the second calendar quarter of 2018.
| Production | 41,000 - 46,000 Mcfe per day | |
| LOE (including transportation and workovers) | $5.9 million - $6.4 million | |
| Production and ad valorem taxes (% of Revenue) | 3.5 - 4.0% | |
| Cash G&A | $4.9 million - $5.4 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
Contango Oil &
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
| 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 |
Source: Contango Oil & Gas