Energia
Talos Energy Announces First Quarter 2019 Financial And Operational Results
President and Chief Executive Officer Timothy S. Duncan commented: "It has been an extremely busy and important time for Talos. Not only is there great focus on our appraisal work in our globally recognized Zama discovery, but we have been very busy in the U.S. Gulf of Mexico , with two subsea well hook-ups and two other prospective deepwater operations. In our Phoenix complex we participated with Helix Energy Solutions ("Helix") in the HP-I dry-dock. The vessel has a regulatory requirement to dry-dock approximately every two and a half years, which this year happened in the first quarter and resulted in approximately 60 days of total planned downtime in the Phoenix complex. The dry-dock project also helps assure the long-term health of the HP-I, which is one of the few floating production facilities in the U.S. Gulf of Mexico . Talos used the dry-dock time wisely, drilling and completing two new subsea wells that were immediately put into production upon the HP-I's return to the Phoenix complex, allowing the Company to reach a production milestone, most recently producing 40.0 thousand barrels of oil per day (47.0 MBoe/d) gross through that facility. Also, the Helix and Talos teams are proud to share an important health and safety milestone aboard the HP-I, as both companies reached eight years and a collective and consecutive two million man-hours without a lost-time incident."
"In offshore Mexico , on the Zama project, our operational execution to date has been outstanding, as we are moving at an accelerated pace and incident free. The ongoing appraisal program continues to validate both the scale and future deliverability of the asset. We are excited to work with our consortium partners and Pemex as we study the quickest path to first production and the full optimization of the resource potential of such an impactful project."
"In the U.S. Gulf of Mexico , we brought online two subsea wells to Talos-operated infrastructure, Tornado 3 and Boris 3. The combined sustained production from those wells was 12.6 MBoe/d net to Talos. In addition, we had encouraging results in the Orlov prospect and have started operations on our Bulleit prospect. The latter, if successful, will tie into a facility we purchased in a highly accretive transaction last year. We also continue to see progress in our shallow water drilling and asset management activities."
"In conclusion, we knew the challenges we were going to face this quarter with an active, front-loaded capital program during a planned shut-in of the Phoenix complex, but we have since restored and increased production with new impactful wells. As our production continues to build during the year, our capital program will taper off following the high volume of activity in the first half of 2019, as previously guided. We continue to execute operationally and are focused on the same goal we delivered in 2018 - generating free cash flow on an annual basis by investing in short-cycle projects with high rates of return, but also generating material value creation through our high-impact exploration and development activities."
As previously announced, Talos and its partners drilled the second penetration in the Zama reservoir to better define the resource potential of the Zama discovery. Building upon the success of the first appraisal penetration (Zama-2), the Zama-2 ST1 well successfully tested the northern limits of the reservoir, acquired over 700 feet of whole core to collect detailed rock properties, and performed successful well tests in several perforated intervals, reaching an unstimulated and restricted combined production rate of 7.9 MBoe/d gross, of which 94% was oil. We believe the tests confirm the deliverability and significant drainage areas of future production wells as well as peak field production.
The next step of the appraisal program is currently underway. Work on the Zama-3 appraisal well was initiated in late April and will assist in delineating the reservoir continuity and quality in the southern part of the field. The Zama-3 appraisal operation includes collecting an additional core to better understand the reservoir geology.
In October of 2018, Talos announced a cross-assignment transaction with a subsidiary of Pan American Energy ("PAE"), pursuant to which Talos conveyed a 25% participation interest (i.e. half of its interest) in the high-risk exploration Block 2 to PAE in exchange for a 25% participation interest from PAE in Block 31, a lower risk project set up by encouraging results in the Xaxamani-1 well.
In the first quarter, Talos added approximately 0.7 MBoe/d net to the Company's production through assorted asset management and well work activities, including workovers and recompletions on wells with stacked pays. The Company recently initiated asset management efforts in the Ram Powell field, purchased in 2018, that are expected to add incremental production in the second quarter.
Production for the first quarter of 2019 was 3.8 MMBoe and was comprised of 2.7 million barrels of oil, 0.3 million barrels of NGLs and 5.2 billion cubic feet ("Bcf") of natural gas. Oil and NGLs production accounted for 77% of the total production for the first quarter of 2019.
As planned and previously disclosed, the HP-I floating production unit underwent regulatorily-mandated dry-dock during the first quarter of 2019, leading to a total shut-in period of 57 days in the Phoenix complex. Talos estimates that approximately 12.1 MBoe/d of production from the Phoenix complex in the quarter was deferred as a result of the HP-I dry-dock. Also during the quarter, the Pompano facility experienced unplanned downtime due to a compressor repair and a third party shut-in at a nearby facility, which deferred approximately 1.5 MBoe/d of production from the field during the quarter. Although a certain level of third party downtime is expected and planned for, these interruptions in production were limited to the first quarter and are not expected to have a material impact going forward.
The Company reaffirms its previously guided annual average daily production range of 53.0 – 56.0 MBoe/d for 2019.
The table below provides additional detail of the Company's oil, natural gas and NGLs production volumes and sales prices per unit for the three months ended March 31, 2019 :
The table below provides additional detail of the Company's production by major assets for the three months ended March 31, 2019 :
Total revenue for the three months ended March 31, 2019 was $178 .7 million, which was impacted by the planned HP-I dry-dock. Total revenue includes $3.5 million of federal royalty refunds, classified as other revenue.
Oil price realizations net of certain gathering, transportation, quality differentials and other costs, continues to be robust, representing an average for the quarter of $3.56 per barrel above the average WTI price for the first quarter of 2019.
The table below summarizes the revenue by commodity for the three months ended March 31, 2019 and provides additional relevant information:
Total LOE for three months ended March 31, 2019 was $45.5 million , inclusive of insurance costs.
Workover and maintenance expense for the three months ended March 31, 2019 was $23.0 million and included approximately $1.5 million of maintenance-related costs in connection with the Whistler acquisition, $2.0 million at our SMI 130 field for repairs and $6.9 million related to the HP-I dry-dock operation repairs and related workover expense within the Phoenix complex in the first quarter of 2019.
General and administrative expense for the three months ended March 31, 2019 was $13.8 million , excluding $1.3 million of stock-based compensation and $2.5 million in transaction-related costs.
Price risk management activities for the three months ended March 31, 2019 resulted in a $3 .0 million expense related to cash settlement on our derivative contracts.
Net loss was $109.6 million , or $2.02 net loss per share, in the first quarter of 2019, as compared to $306.3 million in net income in the fourth quarter of 2018. After certain adjustments, the Adjusted Earnings per Share in the first quarter was $0.19 .
Adjusted EBITDA in the first quarter of 2019 was $93.7 million as compared to $158.8 million in the fourth quarter of 2018. The reduction is attributed to the Phoenix complex being shut-in for approximately two months as a result of the planned dry-dock of the HP-I.
Capital expenditures in the first quarter of 2019 were $155.6 million , inclusive of plugging & abandonment costs. The 2019 capital program is front-loaded in the first half of the year, as all of the currently planned deepwater drilling and completions activities will occur in the first two quarters. Similarly, Talos is appraising the globally recognized Zama discovery offshore Mexico , which is also taking place in the first half of the year.
Talos reaffirms its annual capital expenditure guidance range of
$465 million – $485 million for 2019.
The table below provides additional detail of the Company's capital expenditures:
As of March 31, 2019 , the Company had approximately $682 .4 million in long-term debt, excluding deferred financing costs and original issue discount. The balance includes $396 .9 million of second lien notes, $275 .0 million of borrowings under the Company's credit facility and a $10 .5 million building loan. In addition to the Company's long-term debt, as of March 31, 2019 , Talos had the HP-I finance lease obligation with a balance of approximately $90 .4 million.
As of March 31, 2019 , the Company had a liquidity position of $355.5 million , including $309.8 million available under the $600 .0 million credit facility and approximately $45 .7 million of cash. In the fourth quarter of 2018, the Company's borrowing base was increased by approximately 42% to $850 million ; however, Talos elected to maintain the commitments at $600 million .
Annualized Adjusted EBITDA for the nine month period ended March 31, 2019 was $546 .0 million. As of March 31, 2019 , the Company's total debt was $772 .7 million and Net Debt was $727 .0 million, both including the finance lease. Therefore, the Net Debt to Annualized Adjusted EBITDA ratio of Talos was 1.3x.
Talos will host a conference call, which will also be broadcast live over the internet, on Thursday, May 9, 2019 at 10:00 am Eastern Time ( 9:00 am Central Time ).
Listeners can access the conference call live over the internet through a webcast link on the Company's website at: https://www.talosenergy.com/investors. Alternatively, the conference call can be accessed by dialing 1-888-348-8927 (U.S. toll-free), 1-855-669-9657 ( Canada toll-free) or 1-412-902-4263 (international). Please dial in approximately 15 minutes before the teleconference is scheduled to begin and ask to be joined into the Talos Energy call.
A replay of the call will be available one hour after the conclusion of the conference call through Thursday, May 16, 2019 and can be accessed by dialing 1-877-344-7529 and using access code 10131026.
Sergio Maiworm
+1.713.328.3008
investor@talosenergy.com
This communication may contain "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended (the "Securities Act"), and Section 21E of the Securities Exchange Act of 1934, as amended. All statements, other than statements of historical fact included in this communication, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this communication, the words "could," "believe," "anticipate," "intend," "estimate," "expect," "project" and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on our current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events.
We caution you that these forward-looking statements are subject to numerous risks and uncertainties, most of which are difficult to predict and many of which are beyond our control. These risks include, but are not limited to, commodity price volatility, inflation, lack of availability of drilling and production equipment and services, environmental risks, drilling and other operating risks, regulatory changes, the uncertainty inherent in estimating reserves and in projecting future rates of production, cash flow and access to capital, the timing of development expenditures, potential adverse reactions or changes to competitive responses to the business combination between Talos Energy LLC and Stone Energy Corporation, the possibility that the anticipated benefits of such business combination are not realized when expected or at all, including as a result of the impact of, or problems arising from, the integration of the two companies, and other factors that may affect our future results and business, generally, including those discussed under the heading "Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2018 , filed with the SEC on March 14, 2019 , and in our Quarterly Report on Form 10-Q for the quarter ended March 31, 2019 , to be filed with the SEC subsequent to the issuance of this communication.
Should one or more of these risks occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. All forward-looking statements, expressed or implied, are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, to reflect events or circumstances after the date of this communication.
Estimates for our future production volumes are based on assumptions of capital expenditure levels and the assumption that market demand and prices for oil and gas will continue at levels that allow for economic production of these products. The production, transportation and marketing of oil and gas are subject to disruption due to transportation and processing availability, mechanical failure, human error, hurricanes and numerous other factors. Our estimates are based on certain other assumptions, such as well performance, which may vary significantly from those assumed. Therefore, we can give no assurance that our future production volumes will be as estimated.
Certain financial information included in our financial results are not measures of financial performance recognized by accounting principles generally accepted in the United States , or GAAP. These non-GAAP financial measures are "Adjusted Net Income", "Adjusted Earnings per Share", "Adjusted EBITDA", "Adjusted EBITDA excluding hedges", "Adjusted EBITDA Margin", "Adjusted EBITDA Margin Excluding Hedges", "Net Debt", "Annualized Adjusted EBITDA" and "Net Debt to Annualized Adjusted EBITDA." These disclosures may not be viewed as a substitute for results determined in accordance with GAAP and are not necessarily comparable to non-GAAP measures which may be reported by other companies.
"Adjusted EBITDA" is not a measure of net income (loss) as determined by GAAP. We use this measure as a supplemental measure because we believe it provides meaningful information to our investors. We define Adjusted EBITDA as net income (loss) plus interest expense, income tax expense, depreciation, depletion and amortization, accretion expense, loss on debt extinguishment, transaction related costs, the net change in the fair value of derivatives (mark to market effect, net of cash settlements and premiums related to these derivatives), non-cash (gain) loss on sale of assets, non-cash write-down of oil and natural gas properties, non-cash write-down of other well equipment inventory and non-cash equity based compensation expense. We believe the presentation of Adjusted EBITDA is important to provide management and investors with (i) additional information to evaluate, with certain adjustments, items required or permitted in calculating covenant compliance under our debt agreements, (ii) important supplemental indicators of the operational performance of our business, (iii) additional criteria for evaluating our performance relative to our peers and (iv) supplemental information to investors about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted EBITDA has limitations as an analytical tool and should not be considered in isolation or as a substitute for analysis of our results as reported under GAAP or as an alternative to net income (loss), operating income (loss) or any other measure of financial performance presented in accordance with GAAP.
"Adjusted EBITDA excluding hedges" is defined as Adjusted EBITDA plus net cash receipts (payments) on settled derivative instruments. We believe the presentation of Adjusted EBITDA excluding hedges is important to provide management and investors with information about the impact of actual commodity price changes on our business.
"Adjusted EBITDA Margin" is defined as Adjusted EBITDA divided by Revenue, as a percentage. It is also defined as Adjusted EBITDA divided by the total production volume, expressed in Boe, in the period, and described as dollar per Boe. We believe the presentation of Adjusted EBITDA Margin is important to provide management and investors with information about how much we retain in Adjusted EBITDA terms as compared to the revenue we generate and how much per barrel we generate after accounting for certain operational and corporate costs.
"Adjusted EBITDA margin excluding hedges" bears the same definition and our intended utility of Adjusted EBITDA margin, but using Adjusted EBITDA excluding hedges instead of Adjusted EBITDA.
The following table presents a reconciliation of the GAAP financial measure of net income (loss) to Adjusted EBITDA, from Adjusted EBITDA to Adjusted EBITDA excluding hedges, Adjusted EBITDA margins and Adjusted EBITDA margins excluding hedges for each of the periods indicated (in thousands, except for Boe, $/Boe and percentage data):
"Adjusted Net Income" is not a measure of net income (loss) as determined by GAAP. We use this measure as a supplemental measure because we believe it provides meaningful information to our investors. We define Adjusted Net Income as net income (loss) plus accretion expense, loss on debt extinguishment, transaction related costs, the net change in the fair value of derivatives (mark to market effect, net of cash settlements and premiums related to these derivatives) and non-cash equity based compensation expense. We believe the presentation of Adjusted Net Income is important to provide management and investors with (i) important supplemental indicators of the operational performance of our business, (ii) additional criteria for evaluating our performance relative to our peers and (iii) supplemental information to investors about certain material non-cash and/or other items that may not continue at the same level in the future. Adjusted Net Income has limitations as an analytical tool and should not be considered in isolation or as a substitute for analysis of our results as reported under GAAP or as an alternative to net income (loss), operating income (loss) or any other measure of financial performance presented in accordance with GAAP.
"Adjusted Earnings per Share" is defined as Adjusted Net Income divided by the number of common shares.
"Net Debt" is not a measure of Debt as determined by GAAP. We define Net Debt as the total Debt principal of the Company plus the Finance Lease balance minus Cash.
"Net Debt to Annualized Adjusted EBITDA" is defined as Net Debt divided by the Annualized Adjusted EBITDA.
We believe the presentation of Net Debt, Annualized Adjusted EBITDA and Net Debt to Annualized Adjusted EBITDA is important to provide management and investors with additional important information to evaluate our business. These measures are widely used by investors and ratings agencies in the valuation, comparison, rating and investment recommendations of companies.
The Annualized Adjusted EBITDA information included in this communication provides additional relevant information to our investors and creditors. Talos needs to comply with a financial covenant included in its Bank Credit Facility that requires it to maintain a Net Debt to Annualized Adjusted EBITDA ratio equal to or lower than 3.0x. For purposes of covenant compliance, Annualized Adjusted EBITDA, with certain adjustments, is calculated the following way:
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