Talos Energy Announces Second Quarter 2019 Financial And Operational Results
HOUSTON, Aug. 7, 2019 /PRNewswire/ -- Talos Energy Inc. ("Talos," or the "Company") (NYSE: TALO) today announced its financial and operational results for the second quarter of 2019 and an operations update.
Key second quarter highlights include:
-- Production of 59.0 thousand barrels of oil equivalent per day
("MBoe/d"), or 5.4 million barrels of oil equivalent ("MMBoe") in total,
of which 75% was oil and 81% was liquids.
-- Revenue((1)) of $286.8 million and average realized prices of $64.13/Bbl
of oil and $2.45/Mcf of natural gas, net of deductions. 92% of operating
revenues were derived from oil production and reflect a significant
basis differential premium to the average WTI benchmark price of
$59.81/Bbl during the same period.
-- Net Income of $94.8 million ($1.74 earnings per share - diluted) and
Adjusted Net Income((2)) of $67.8 million ($1.25 adjusted earnings per
share - diluted).
-- Adjusted EBITDA((2)) of $206.9 million. Adjusted EBITDA excluding
hedges((2)) in the quarter was $216.5 million.
-- Adjusted EBITDA Margin((2)) per Boe of $38.54, or approximately 72%, and
Adjusted EBITDA Margin excluding hedges((2)) per Boe of $40.32, or
approximately 75%. The Company's Adjusted EBITDA Margin excluding
hedges((2)) on a percentage basis is the highest in Talos's history.
-- As of June 30, 2019, liquidity position of $358.9 million, including
$269.8 million available under the Bank Credit Facility and
approximately $89.1 million of cash. Pro forma for the Company's credit
facility commitment increase to $850.0 million on July 3, liquidity was
$608.9 million.
-- As of June 30, 2019, the Company's total debt principal balance was
$798.8 million, inclusive of the $86.9 million finance lease on the
HP-I. Net Debt to Last Twelve Months ("LTM") Adjusted EBITDA((2)) was
1.2x. Net Debt to the annualized second quarter 2019 Adjusted
EBITDA((2)) ("Annualized Adjusted EBITDA") is less than 0.9x.
-- Capital expenditures, inclusive of plugging and abandonment costs, were
$187.4 million with approximately $156.2 million related to the U.S.
Gulf of Mexico and $31.2 million related to offshore Mexico.
-- With a capital program front-loaded in the first half of 2019, the
Company participated in five drilling projects in the second quarter,
with success in the Bulleit and Orlov projects in the deepwater U.S.
Gulf of Mexico, new production established in the Ewing Bank drilling
program in the shallow water U.S. Gulf of Mexico, the successful
conclusion of the Zama appraisal and the ongoing program in the Block 2
and 31 contractual areas in offshore Mexico.
(1) Includes $8.5 million of federal
royalty refund.
(2) Adjusted Net Income, Adjusted
Earnings per Share, Adjusted
EBITDA, Adjusted EBITDA excluding
hedges, Adjusted EBITDA Margin and
Adjusted EBITDA Margin excluding
hedges, Net Debt to LTM Adjusted
EBITDA and Net Debt to Annualized
Adjusted EBITDA are non-GAAP
financial measures. See
"Supplemental Non-GAAP
Information" below for additional
detail and reconciliations of GAAP
to non-GAAP measures.
President and Chief Executive Officer Timothy S. Duncan commented: "I am pleased with the Company's performance during the second quarter of 2019. This was the Company's best quarter on record in terms of production, Adjusted EBITDA, and Adjusted EBITDA Margin excluding hedges on a percentage basis, even with lower commodity prices and slightly higher service costs from a year ago. These strong results highlight our well-executed in-basin consolidation and the industrial logic of our business combination with Stone Energy that closed in the second quarter of 2018, as well as the benefits of our strategy of drilling in and around infrastructure we own or have access to, strong asset management and a continued focus on controlling costs.
"We executed numerous successful drilling projects in both deepwater and shallow water in the U.S. Gulf of Mexico and two drilling programs in offshore Mexico. Our annual capital program was significantly front-loaded in the first half of the year with five rigs working during the second quarter. Even with this high level of activity, our U.S. Gulf of Mexico business generated meaningful free cash flow in the second quarter. We believe that reinvesting cash flows from the U.S. Gulf of Mexico business into our globally recognized Zama discovery will help accelerate the value realization of that asset, and we are extremely proud of our progress on that front. In the second half of the year, we expect to continue generating a significant amount of free cash flow from our U.S. Gulf of Mexico business that will be further enhanced by having concluded the Zama appraisal in the second quarter.
"We further strengthened our financial profile in the second quarter with a $250 million increase to our credit facility commitments and the addition of incremental 2020 hedges at attractive average pricing. These improvements will allow the Company to maintain optionality and flexibility as we move forward, underpinned by our peer-leading balance sheet and leverage profile."
RECENT DEVELOPMENTS AND OPERATIONS UPDATE
Drilling and Exploration Activities - U.S. Gulf of Mexico
Deepwater
-- Bulleit Prospect: Drilling operations are concluding on the Green Canyon
21 Bulleit prospect. The well encountered approximately 140 feet of net
true vertical depth ("TVD") oil pay in the shallow target, the DTR-10
Sand, and approximately 110 feet of net TVD oil pay in the deeper MP
Sand. Talos experienced delays and additional costs during drilling due
to difficult hole conditions below the DTR-10 Sand that necessitated a
side track of the original well path to a new directional plan.
Additionally, the rig was moved off location to ensure safe operations
during Hurricane Barry. The well will be completed in the first half of
2020 and then tied back to the Talos-owned and operated Green Canyon 18
("GC 18") facility located approximately 10 miles west of Bulleit. The
Bulleit prospect, originally generated by EnVen Energy ("EnVen"), is now
50.0% owned and operated by Talos, with EnVen and Otto Energy owning
33.3% and 16.7%, respectively.
-- Orlov Prospect: The Green Canyon 200 Orlov prospect initially
encountered approximately 100 feet of net true vertical thickness
("TVT") oil pay in the main target Aspen J sand, as well as additional
pay sands in shallower zones along the same trap. The operator,
Fieldwood Energy ("Fieldwood"), currently has a rig on location and will
soon commence an operation to re-enter the well and drill an appraisal
sidetrack to optimize the well location in relation to the discovered
resources. Initial production from Orlov is expected in the first
quarter of 2020 and will be tied back to the Fieldwood-operated
Bullwinkle facility. Talos owns a 30% working interest in the Orlov
project.
Shallow Water
-- Ewing Bank 306 A-2 ST-2: Production was brought online via a dual
completion in the deepest two of five hydrocarbon-bearing zones in the
first week of May of 2019 at a production rate of approximately 1.3
MBoe/d gross, 1.0 MBoe/d net to Talos. Subsequently, the well reached a
production rate of approximately 1.7 MBoe/d gross, 1.4 MBoe/d net to
Talos. Talos owns a 100% working interest in the project.
-- Ewing Bank 306 A-10 ST-2: The A-10 ST-2 was successfully drilled in the
second quarter, finding approximately 95 feet of net TVD pay in the
Miocene geological section that was first discovered in the A-20 ST well
drilled in 2018. Production was brought online on July 24 of 2019 and
reached a production rate of approximately 2.6 MBoe/d gross, 2.1 MBoe/d
net to Talos. Talos owns a 100% working interest in the project.
-- Grand Isle 82 A-22: Drilling commenced on July 2 and will target a
series of Miocene sands at approximately 14,600 feet TVD. If successful,
Talos expects the well to generate an initial production rate of 2.5 -
3.5 MBoe/d gross, 2.2 - 3.1 MBoe/d net to Talos, with first production
expected in the fourth quarter of 2019. Talos owns a 100% working
interest in the project.
Drilling and Exploration Activities - Mexico
Block 7 - Zama Appraisal Program
-- Completion of Appraisal Program: Talos has concluded its three-well
appraisal of the Zama discovery with highly encouraging results. The
Zama-3 well was drilled to test the southern extent of the reservoir.
Well results included the logging of approximately 1,000 feet of gross
TVD sand and 748 feet of gross TVD oil pay, with better than expected
net-to-gross ratios across the pay sections and the capture of a new
record whole core (717 feet). The Zama appraisal program was completed
39 days ahead of schedule and under budget. Appraisal operations were
successfully completed with zero lost-time incidents or environmental
issues.
-- Appraisal Data: Throughout the appraisal program, Talos collected a
substantial amount of data, including approximately 1,450 feet of whole
core, 59 fluid samples from the reservoir, over 200 pressure points, 25
logging runs and two extended flow tests. This data will be incorporated
into an independent, third party resource estimate to be prepared by
Netherland, Sewell & Associates, Inc. by year end 2019. Talos expects
updated resource guidance to fall in the upper half of its previously
disclosed pre-appraisal estimated range of gross recoverable resources
of 400 - 800 MMBoe.
-- Progress to FID: Front-End Engineering & Design ("FEED") work is
advancing via an engagement with io Oil & Gas Consulting (a joint
venture between Baker Hughes GE and McDermott International, Inc.) to
optimize the recovery and economic development of the field. Talos has
significantly narrowed the number of potential development concepts and
the prevailing concept design will be the basis for development.
Additionally, unitization discussions with Petróleos Mexicanos
("Pemex") are ongoing with the goal of reaching a Final Investment
Decision ("FID") in 2020.
Block 2 and Block 31 Exploration Program
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 Block 2 to PAE in exchange for a 25% participation interest from PAE in Block 31, resulting in a four well program consisting of two wells on each of Blocks 2 and 31.
-- Block 2: The Yaluk-1EXP, the second well on Block 2, was drilled in the
second quarter of 2019 and encountered a non-commercial quantity of
hydrocarbons. Net costs to Talos were approximately $8.0 million.
-- Block 31: The first project on Block 31, the Xaxamani-2EXP well, spud in
July and reached total depth ("TD") in early August with encouraging
results. It is the first well in the Olmeca project area, which is a
shallow oil project set up by the Xaxamani-1 exploratory well drilled in
2003, which logged oil pay in several intervals. PAE expects to perform
a drill stem test in the Xaxamani-2EXP before moving to the Tolteca
well, which has similar objectives. The project is located in very
shallow waters (approximately 60 feet) and less than two miles from
shore. Talos will provide more details at the conclusion of the program.
Asset Management Activities
In the second quarter of 2019, Asset Management workover and recompletion activities accounted for incremental production of 0.9 MBoe/d gross, 0.7 MBoe/d, net to Talos. Asset Management-related capital expenditures in the second quarter also included $8 million related to a recompletion campaign on two wells in the Pompano field, for which production did not start until July. The Pompano A-5 well was finalized on July 5 and is currently producing approximately 1.1 MBoe/d gross, 1.0 MBoe/d, net to Talos. The Cardona #6 subsea well was recompleted on July 17 and is producing approximately 2.6 MBoe/d gross, 1.5 MBoe/d, net to Talos. The combined production conversion cost of these two wells is $3,200/Boe/d, with the production impact beginning in the third quarter of 2019.
Liquidity and Derivatives Activities
-- Borrowing Base & Liquidity: Effective July 3, Talos elected to increase
commitments under its syndicated credit facility to the reaffirmed
borrowing base level of $850 million, up from $600 million in the first
half of 2019. After adjusting June 30 figures for the revised commitment
level, pro forma liquidity, including cash, would be $608.9 million,
with 39% of the facility drawn. In addition, Talos added three
additional lenders to the syndicate.
-- Hedging Updates: In the second quarter Talos added additional hedging of
2020 oil production of approximately 3.4 million barrels. As of June 30,
2019, the Company's weighted average swap price for 2020 is $56.80/bbl
and the weighted average put and call prices for the costless collars
were $55.00 and $64.23, respectively.
SECOND QUARTER 2019 RESULTS
Key Financial Highlights:
Three months ended
June 30, 2019
Period
Results ($
million,
except per
share and
Boe):
Revenues(1) $
286.8
Net Income $
94.8
Net Income
per diluted
share $
1.74
Adjusted Net
Income(2) $
67.8
Adjusted
Earnings per
diluted
share(2) $
1.25
Adjusted
EBITDA(2) $
206.9
Adjusted
EBITDA excl.
hedges(2) $
216.5
Capital
Expenditures
(including
Plugging &
Abandonment) $
187.4
Adjusted
EBITDA
Margin(2):
Adjusted
EBITDA (% of
Revenue) 72
%
Adjusted
EBITDA per
Boe $
38.54
Adjusted
EBITDA excl.
hedges (% of
Revenue) 75
%
Adjusted
EBITDA excl.
hedges per
Boe $
40.32
Production, Realized Prices and Revenue
Production: Production for the second quarter of 2019 was 5.4 million barrels of oil equivalent, comprised of 4.0 million barrels of oil, 0.4 million barrels of NGLs and 6.0 billion cubic feet ("Bcf") of natural gas. Oil and NGL production accounted for 81% of the total production for the second quarter of 2019.
Realized Prices: Oil price realizations, net of certain gathering, transportation, quality differentials and other costs, was $64.13 per barrel. Realizations continues to be robust, representing an average for the quarter of $4.32 per barrel above the average WTI price over the same period.
Revenue: Total revenue for the three months ended June 30, 2019 was $286.8 million. Total revenue includes $8.5 million of federal royalty refunds, classified as other revenue.
Three months ended
June 30, 2019
Production Volumes:
Oil production volume
(MBbls) 4,006
NGL production volume
(MBbls) 362
Natural Gas
production volume
(MMcf) 6,008
Total production
volume (MBoe) 5,369
Average Net Daily
Production Volumes:
Oil (MBbl/d) 44.0
NGL (MBbl/d) 4.0
Natural Gas (MMcf/d) 66.0
Total average net
daily volume (MBoe/
d) 59.0
Average Realized
Prices (excluding
hedges)(3):
Oil ($/Bbl) 64.13
NGL ($/Bbl) 18.36
Natural Gas ($/Mcf) 2.45
Average Realized
Price ($/Boe) 51.83
Average NYMEX Prices:
WTI ($/Bbl) 59.81
Henry Hub ($/MMBtu) 2.64
Revenues ($ million):
Oil 256.9
NGL 6.6
Natural Gas 14.8
Operating Revenue 278.3
Other revenue 8.5
Total revenue 286.8
The table below provides additional detail of the Company's production by major assets for the three months ended June 30, 2019:
Three months ended June 30, 2019
Production % Oil % Liquids % Operated
Average Net
Daily
Production
Volumes by
Asset (MBoe/
d):
Green Canyon
Phoenix Complex 22.8 80
% %
% 87 100
Green Canyon 18 1.1 88
% %
% 89 100
Green Canyon 81
Area
%
%
23.9 % 87 100
Mississippi
Canyon
Amberjack 2.1 91
% %
% 93 100
Pompano 11.5 84
% %
% 90 100
Ram Powell 5.8 57
% %
% 70 100
Gunflint 1.3 78
% %
% 88 0
Mississippi 77
Canyon Area
%
%
20.7 % 84 94
Shelf and Other
Deepwater
Shelf 12.7 60
% %
% 66 89
Other Deepwater 1.7 71
% %
% 78 71
Shelf and Other 61
Deepwater Area
%
%
14.4 % 67 87
Total average 75
net daily
volumes (MBoe/ %
d) %
59.0 % 81 95
Subsequent Events: Production from the U.S. Gulf of Mexico was significantly impacted in the month of July due to precautionary shut-ins of facilities and evacuations associated with Hurricane Barry. According to the Bureau of Safety and Environmental Enforcement's ("BSEE") daily reports, impacts from the storm peaked on July 14 resulting in approximately 1.4 million barrels per day of oil production shut-in, or 73% of all U.S. Gulf of Mexico oil production. Although there was no major storm related damage, the production impact to Talos spanned approximately one week and also peaked on July 14 with Talos shutting in approximately 85% of its production in the period. Talos expects the production deferral from Hurricane Barry to impact only the third quarter of 2019 financial results.
Production rates from the Boris #3 well, which significantly surpassed Talos's initial production expectation when the well was brought online in the last week of April, have recently stabilized near the low end of the Company's pre-drill estimated range of 3.0 - 5.0 MBoe/d gross, or 2.8 - 4.6 MBoe/d net to Talos after royalties.
As a result of Hurricane Barry and stabilization of the Boris #3 production rate, Talos expects average daily production in the third quarter of 2019 to be negatively impacted by approximately 4.0 - 6.0 MBoe/d, net to Talos, relative to the Company's expectations.
Expenses
Lease operating expenses ("LOE"): Total LOE for three months ended June 30, 2019 was $42.7 million, inclusive of insurance costs. LOE per Boe for the quarter was $7.95/Boe.
Workover and maintenance expenses: Workover and maintenance expense for the three months ended June 30, 2019 was $12.3 million. Workover and maintenance expenses per Boe for the quarter was $2.29/Boe.
General and administrative expenses ("G&A"): General and administrative expenses for the three months ended June 30, 2019 were $16.2 million, excluding $2.0 million of stock-based compensation and $0.7 million in transaction-related costs. G&A per Boe for the quarter was $3.02/Boe.
Three months ended
$ / Boe
June 30, 2019
Lease Operating Expenses $
42.7 $
7.95
Workover and Maintenance
Expenses $
12.3 $
2.29
General & Administrative
Expenses (excluding non-
cash items) $
16.2 $
3.02
Price risk management activities: Price risk management activities for the three months ended June 30, 2019 resulted in a $9.5 million cash payment on our derivative contracts.
Other Financial Metrics
Net income, Adjusted Earnings per Share and Adjusted EBITDA: Net income was $94.8 million, or $1.74 earnings per diluted share. After certain adjustments, the Adjusted Earnings per Diluted Share in the second quarter was $1.25. Adjusted EBITDA in the second quarter of 2019 was $206.9 million.
Capital Expenditures: Capital expenditures in the second quarter of 2019 were $187.4 million, inclusive of plugging & abandonment costs. The table below provides additional detail of the Company's capital expenditures:
($ millions) Three months ended
June 30, 2019
U.S. drilling &
completions $
85.8
Mexico appraisal &
exploration 30.0
Asset management 24.5
Seismic and G&G /
Land /Capitalized
G&A(4) 18.9
Total Capital
Expenditures 159.2
Plugging &
Abandonment 28.3
Total Capital
Expenditures and
Plugging &
Abandonment $
187.4
Financial position: As of June 30, 2019, the Company had approximately $798.8 million in total debt, including deferred financing costs and original issue discount. The balance includes $396.9 million of second lien notes, $315.0 million of borrowings under the Company's credit facility and the HP-I finance lease obligation with a balance of approximately $86.9 million.
Liquidity position: As of June 30, 2019, liquidity position of $358.9 million, including $269.8 million available under the Bank Credit Facility and approximately $89.1 million of cash. Pro forma for the Company's credit facility commitment increase on July 3, liquidity was $608.9 million.
Leverage and credit metrics: LTM Adjusted EBITDA for the twelve month period ended June 30, 2019 was $616.4 million. As of June 30, 2019, the Company's total debt was $798.8 million and Net Debt was $709.7 million, both including the finance lease. Therefore, Net Debt to LTM Adjusted EBITDA ratio was 1.2x. Net Debt to an annualized second quarter 2019 Adjusted EBITDA is less than 0.9x.
(1) Includes $8.5 million of federal
royalty refund.
(2) Adjusted Net Income, Adjusted
Earnings per Share, Adjusted
EBITDA, Adjusted EBITDA excluding
hedges, Adjusted EBITDA Margin and
Adjusted EBITDA Margin excluding
hedges, Net Debt to LTM Adjusted
EBITDA and Net Debt to Annualized
Adjusted EBITDA are non-GAAP
financial measures. See
"Supplemental Non-GAAP
Information" below for additional
detail and reconciliations of GAAP
to non-GAAP measures.
(3) Average realized prices are net of
certain gathering, transportation,
quality differentials and other
costs.
(4) Includes $1.2 million of Mexico
expenditures.
CONFERENCE CALL AND WEBCAST INFORMATION
Talos will host a conference call, which will also be broadcast live over the internet, on August 8, 2019 at 10:00 AM CT. 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 August 15, 2019 and can be accessed by dialing 1-877-344-7529 and using access code 10133698.
ABOUT TALOS ENERGY
Talos Energy (NYSE: TALO) is a technically driven independent exploration and production company focused on safely and efficiently maximizing cash flows and long-term value through its operations, currently in the United States Gulf of Mexico and offshore Mexico. As one of the U.S. Gulf of Mexico's largest public independent producers, we leverage decades of geology, geophysics and offshore operations expertise towards the acquisition, exploration, exploitation and development of assets in key geological trends that are present in many offshore basins around the world. Our activities in offshore Mexico provide high impact exploration opportunities in an oil rich emerging basin. For more information, visit www.talosenergy.com.
INVESTOR RELATIONS CONTACT
Sergio Maiworm
+1.713.328.3008
investor@talosenergy.com
CAUTIONARY STATEMENT ABOUT FORWARD-LOOKING STATEMENTS
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," "forecast, "may," "objective," plan" 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 June 30, 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.
TALOS ENERGY INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
(In thousands, except share amounts)
June 30, 2019 December 31, 2018
(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents $
89,105 $
139,914
Restricted cash 1,248
Accounts receivable
Trade, net 110,504 103,025
Joint interest, net 35,741 20,244
Other 28,828 19,686
Assets from price risk management activities 23,633 75,473
Prepaid assets 38,370 38,911
Income tax receivable 10,701
Other current assets 2,085 7,644
Total current assets 328,266 416,846
Property and equipment:
Proved properties 3,925,116 3,629,430
Unproved properties, not subject to amortization 165,041 108,209
Other property and equipment 28,244 33,191
Total property and equipment 4,118,401 3,770,830
Accumulated depreciation, depletion and
amortization (1,879,486) (1,719,609)
Total property and equipment, net 2,238,915 2,051,221
Other long-term assets:
Assets from price risk management activities 5,508
Other well equipment inventory 9,914 9,224
Operating lease assets 6,732
Other assets 2,700 2,695
Total assets $
2,592,035 $
2,479,986
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable $
115,086 $
51,019
Accrued liabilities 186,354 188,650
Accrued royalties 42,651 38,520
Current portion of long-term debt 443
Current portion of asset retirement obligations 65,757 68,965
Liabilities from price risk management activities 18,781 550
Accrued interest payable 10,068 10,200
Current portion of operating lease liabilities 1,315
Other current liabilities 18,140 22,071
Total current liabilities 458,152 380,418
Long-term liabilities:
Long-term debt, net of discount and deferred
financing costs 697,130 654,861
Asset retirement obligations 327,583 313,852
Liabilities from price risk management activities 2,464
Operating lease liabilities 15,637
Other long-term liabilities 93,028 123,359
Total liabilities 1,593,994 1,472,490
Commitments and contingencies (Note 11)
Stockholders' equity:
Preferred stock, $0.01 par value; 30,000,000
shares authorized; no shares issued or
outstanding as of June 30, 2019 and December
31, 2018
Common stock $0.01 par value; 270,000,000 shares
authorized; 54,191,693 and 54,155,768 shares
issued and outstanding as of June 30,
2019 and December 31, 2018, respectively 542 542
Additional paid-in capital 1,339,507 1,334,090
Accumulated deficit (342,008) (327,136)
Total stockholders' equity 998,041 1,007,496
Total liabilities and stockholders' equity $
2,592,035 $
2,479,986
TALOS ENERGY INC.
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In thousands, except per common share amounts)
(Unaudited)
Three Months Ended June 30, Six Months Ended June 30,
2019 2018 2019 2018
Revenues and other:
Oil revenue $
256,908 $
180,161 $
412,587 $
307,854
Natural gas revenue 14,746 16,448 29,193 29,171
NGL revenue 6,645 7,297 11,711 12,731
Other 8,511 12,032
Total revenue 286,810 203,906 465,523 349,756
Operating expenses:
Direct lease operating expense 37,975 34,060 78,804 58,975
Insurance 4,184 4,259 8,295 6,934
Production taxes 506 564 1,088 955
Total lease operating expense 42,665 38,883 88,187 66,864
Workover and maintenance expense 12,296 17,714 35,315 24,619
Depreciation, depletion and amortization 95,806 67,726 160,393 116,766
Write-down of oil and natural gas
properties 12,361 12,361
Accretion expense 9,945 9,492 19,552 14,252
General and administrative expense 18,865 30,880 36,474 39,460
Total operating expenses 191,938 164,695 352,282 261,961
Operating income 94,872 39,211 113,241 87,795
Interest expense (24,932) (21,678) (50,150) (41,420)
Price risk management activities income
(expense) 29,990 (91,176) (79,589) (143,152)
Other income (expense) 831 (1,269) 1,264 (1,078)
Income (loss) before income taxes 100,761 (74,912) (15,234) (97,855)
Income tax (expense) benefit (5,997) 362
Net income (loss) $
94,764 $
(74,912) $
(14,872) $
(97,855)
Net income (loss) per common share:
Basic $
1.75 $
(1.69) $
(0.27) $
(2.59)
Diluted $
1.74 $
(1.69) $
(0.27) $
(2.59)
Weighted average common shares outstanding:
Basic 54,178 44,336 54,167 37,826
Diluted 54,451 44,336 54,167 37,826
TALOS ENERGY INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(In thousands)
(Unaudited)
Six Months Ended June 30,
2019 2018
Cash flows from operating activities:
Net loss $
(14,872) $
(97,855)
Adjustments to reconcile net loss to net cash
provided by operating activities
Depreciation, depletion, amortization and
accretion expense 179,945 131,018
Write-down of oil and natural gas properties 12,361
Amortization of deferred financing costs and
original issue discount 2,393 2,607
Equity based compensation, net of amounts
capitalized 3,220 1,559
Price risk management activities expense 79,589 143,152
Net cash paid on settled derivative
instruments (12,562) (54,056)
Settlement of asset retirement obligations (32,206) (43,896)
Changes in operating assets and liabilities:
Accounts receivable (32,118) 19,462
Other current assets 12,259 (13,576)
Accounts payable 23,646 (53,126)
Other current liabilities (37,164) 52,543
Other non-current assets and liabilities,
net (1,870) 19,279
Net cash provided by operating activities 182,621 107,111
Cash flows from investing activities:
Exploration, development and other capital
expenditures (229,601) (140,968)
Cash (paid for) acquired in acquisitions (32,916) 293,001
Proceeds from sale of other property and
equipment 5,369
Net cash provided by (used in) investing
activities (257,148) 152,033
Cash flows from financing activities:
Redemption of Senior Notes and other long-
term debt (10,567) (25,046)
Proceeds from Bank Credit Facility 75,000 294,000
Repayment of Bank Credit Facility (25,000) (54,000)
Repayment of LLC Bank Credit Facility (403,000)
Other deferred payments (9,921) (17,469)
Payments of finance lease (6,759) (6,958)
Employee stock transactions (283)
Net cash provided by (used in) financing
activities 22,470 (212,473)
Net increase (decrease) in cash, cash
equivalents and restricted cash (52,057) 46,671
Cash, cash equivalents and restricted cash:
Balance, beginning of period 141,162 33,433
Balance, end of period $
89,105 $
80,104
Supplemental Non-Cash Transactions:
Capital expenditures included in accounts
payable and accrued liabilities $
165,310 $
38,205
Supplemental Cash Flow Information:
Interest paid, net of amounts capitalized $
31,413 $
23,635
SUPPLEMENTAL NON-GAAP INFORMATION
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", "LTM Adjusted EBITDA," "Annualized Adjusted EBITDA," "Net Debt to LTM 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.
Reconciliation of Net Income (Loss) to Adjusted EBITDA; reconciliation of Adjusted EBITDA Margin
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.
Reconciliation of Net Income (Loss) to Adjusted EBITDA; reconciliation of Adjusted EBITDA Margin
"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, $/Boe and percentage data):
($ thousands, except
per Boe) Three Months Three Months Three Months Three Months
Ended, Ended, Ended, Ended,
September 30, December 31, March 31, June 30,
2018 2018 2019 2019
Reconciliation of net
income (loss) to
Adjusted EBITDA:
Net income (loss) $
13,109 $
306,286 $
(109,636) $
94,764
Interest expense 24,837 23,857 25,218 24,932
Income Tax Expense
(Benefit) 2,922 (6,359) 5,997
Depreciation,
depletion and
amortization 87,808 84,145 64,587 95,806
Write-down of oil and
natural gas
properties 12,361
Accretion expense 10,162 10,930 9,607 9,945
Loss on debt
extinguishment 356
Transaction related
costs 7,595 4,579 2,493 710
Derivative fair value
(gain) loss(1) 53,330 (256,917) 109,579 (29,990)
Net cash receipts
(payments) on settled
derivative
instruments(1) (40,746) (16,345) (3,019) (9,543)
Non-cash (gain) loss
on sale of assets (1,710)
Non-cash write-down
of other well
equipment inventory 244
Non-cash equity-
based compensation
expense 570 764 1,259 1,961
---
Adjusted EBITDA $
157,021 $
158,755 $
93,729 $
206,943
===
Net cash receipts
(payments) on settled
derivative
instruments(1) 40,746 16,345 3,019 9,543
---
Adjusted EBITDA
excluding hedges $
197,767 $
175,100 $
96,748 $
216,486
===
Production and
Revenue:
Boe(2) 5,052 4,910 3,782 5,369
Revenue 282,868 258,664 175,192 278,299
Adjusted EBITDA margin
and Adjusted EBITDA
excl hedges margin:
Adjusted EBITDA
divided by Revenue % % % %
(%) 56 61 54 72
Adjusted EBITDA per
Boe(2) $
31.08 $
32.33 $
24.78 $
38.54
Adjusted EBITDA excl
hedges divided by % % % %
Revenue (%) 70 68 55 75
Adjusted EBITDA excl
hedges per Boe(2) $
39.15 $
35.66 $
25.58 $
40.32
(1) The adjustments for the
derivative fair value (gain)
loss and net cash receipts
(payments) on settled derivative
instruments have the effect of
adjusting net income (loss) for
changes in the fair value of
derivative instruments, which
are recognized at the end of
each accounting period because
we do not designate commodity
derivative instruments as
accounting hedges. This results
in reflecting commodity
derivative gains and losses
within Adjusted EBITDA on a cash
basis during the period the
derivatives settled.
(2) One Boe is equal to six Mcf of
natural gas or one Bbl of oil or
NGLs based on an approximate
energy equivalency. This is an
energy content correlation and
does not reflect a value or
price relationship between the
commodities.
Reconciliation of Adjusted Net Income and Adjusted Earnings per Share
"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.
($ thousands,
except per
share amounts) Three Months Ended,
June 30, 2019
Reconciliation
of Net Income
to Adjusted Net
Income:
Net income $
94,764
Accretion
expense 9,945
Transaction
related costs 710
Derivative fair
value (gain)
loss(1) (29,990)
Net cash
receipts
(payments) on
settled
derivative
instruments(1) (9,543)
Non-cash
equity-based
compensation
expense 1,961
Adjusted Net
Income $
67,847
Weighted average
common shares
outstanding at
June 30, 2019:
Basic 54,178
Diluted 54,451
Net Income per
common share
(Income Per
Share):
Basic $
1.75
Diluted $
1.74
Adjusted Net
Income per
common share
(Adjusted
Earnings Per
Share):
Basic $
1.25
Diluted $
1.25
(1) The adjustments for the
derivative fair value (gain)
loss and net cash receipts
(payments) on settled
derivative instruments have
the effect of adjusting net
income (loss) for changes in
the fair value of derivative
instruments, which are
recognized at the end of each
accounting period because we
do not designate commodity
derivative instruments as
accounting hedges. This
results in reflecting
commodity derivative gains and
losses within Adjusted EBITDA
on a cash basis during the
period the derivatives
settled.
Reconciliation of Net Debt, Net Debt to LTM Adjusted EBITDA and Net Debt to Annualized Adjusted EBITDA
"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 LTM Adjusted EBITDA" is defined as Net Debt divided by the LTM Adjusted EBITDA.
"Net Debt to Annualized Adjusted EBITDA" is defined as Net Debt divided by the Annualized Adjusted EBITDA.
We believe the presentation of Net Debt, LTM Adjusted EBITDA and Net Debt to LTM 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.
Reconciliation of Net Debt ($
thousand) at June 30, 2019:
Debt principal $
711,928
Finance Lease 86,910
Gross Debt $
798,838
Cash (89,105)
Net Debt $
709,733
Reconciliation of LTM Adjusted
EBITDA:
Adjusted EBITDA for the three month
period ended September 30, 2018 $
157,021
Adjusted EBITDA for the three month
period ended December 31, 2018 158,755
Adjusted EBITDA for the three month
period ended March 31, 2019 93,729
Adjusted EBITDA for the three month
period ended June 30, 2019 206,943
LTM Adjusted EBITDA $
616,448
Reconciliation of Annualized Adjusted
EBITDA:
Adjusted EBITDA for the three month
period ended June 30, 2019 $
206,943
x4
Annualized Adjusted EBITDA $
827,772
Reconciliation of Net Debt to
Adjusted EBITDA
Net Debt /LTM Adjusted EBITDA
1.15x
The 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 LTM Adjusted EBITDA ratio equal to or lower than 3.0x. For purposes of covenant compliance, LTM Adjusted EBITDA, with certain adjustments, is calculated, as of June 30, 2019 and in subsequent quarters, as the sum of quarterly Adjusted EBITDA for the 12-month period ended on that quarter.
View original content to download multimedia:http://www.prnewswire.com/news-releases/talos-energy-announces-second-quarter-2019-financial-and-operational-results-300898374.html
SOURCE Talos Energy
