Talos Energy Announces Second Quarter 2024 Operational and Financial Results

In This Article:

HOUSTON, Texas, Aug. 7, 2024 /PRNewswire/ -- Talos Energy Inc. ("Talos" or the "Company") (NYSE: TALO) today announced its operational and financial results for fiscal quarter ended June 30, 2024. Talos also provided third quarter 2024 production guidance and reiterated its operational and financial guidance for the full year 2024.

(PRNewsfoto/Talos Energy)
(PRNewsfoto/Talos Energy)

Key Highlights

  • Production of 95.5 thousand barrels of oil equivalent per day ("MBoe/d") (73% oil, 81% liquids), which is at the high end of Talos's second quarter 2024 guidance range.

  • Repurchased 3.8 million shares of common stock for approximately $43 million at an average price of $11.26 per share, and Talos's Board of Directors authorized an additional $150 million for Talos's existing common stock repurchase program.

  • Reduced debt by $100 million, maintaining leverage at 1.0x* and liquidity of $738.7 million at the end of the second quarter.

  • Purchased a 21.4% working interest ("W.I.") in the Monument discovery located in the Walker Ridge area in the Gulf of Mexico.

  • Returned the Helix Producer I ("HP-I") to service ahead of schedule.

  • Completed integration for QuarterNorth acquisition and increased expected synergies to $35 million since March 2024.

Second Quarter Summary

  • Revenue of $549.2 million, driven by realized prices (excluding hedges) of $80.50 per barrel for oil, $22.33 per barrel for natural gas liquids ("NGLs"), and $2.59 per thousand cubic feet ("Mcf") for natural gas.

  • Net Income of $12.4 million, or $0.07 Net Income per diluted share, and Adjusted Net Income* of $5.2 million, or $0.03 Adjusted Net Income per diluted share*.

  • Adjusted EBITDA* of $344.0 million.

  • Capital expenditures of $122.8 million, excluding plugging and abandonment and settled decommissioning obligations.

  • Net cash provided by operating activities of $289.4 million.

  • Adjusted Free Cash Flow* of $148.0 million.

Talos President and Chief Executive Officer Tim Duncan stated, "The second quarter 2024 marked our first full quarter following the closing of the QuarterNorth transaction, resulting in record levels of production, Adjusted EBITDA, and Adjusted Free Cash Flow. This achievement enabled us to remain on track with our debt repayments while opportunistically buying back 3.8 million shares, representing 2% of our market capitalization. Our team's hard work and commitment have put us ahead of schedule on our integration efforts, leveraging the advantages of our increased scale and diversity.

"In our capital drilling program, the Lobster waterflood project commenced water injection in the second quarter 2024, and we anticipate a positive impact on production rates by 2025. We are currently drilling at our non-operated Ewing Bank 953, with results expected later in the third quarter 2024. Additionally, we anticipate receiving the West Vela deepwater rig late in the third quarter 2024, which will begin drilling three consecutive high-impact subsalt wells, including the Katmai West #2 appraisal in 2024, followed by the Daenerys and Helms Deep prospects in 2025.

"Subsequent to the second quarter 2024, we executed an important transaction securing a 21.4% non-operated interest in the Monument deepwater discovery. The Monument discovery presents an attractive post-FID subsea tie-back opportunity with gross resource potential exceeding 150 MMBoe, including a potential drilling opportunity beyond the appraised discovery. We have built a meaningful acreage position within the prolific Wilcox play in the deepwater Gulf of Mexico, and Monument represents the first of several potential investments in this well-established geological trend. We are pleased to have added this project to our projected 2024 capital program."

Footnotes:
*See "Supplemental Non-GAAP Information" for details and reconciliations of GAAP to non-GAAP financial measures.

RECENT DEVELOPMENTS AND OPERATIONS UPDATE

Shareholder Return Program: In June 2024, Talos opportunistically repurchased 3.8 million shares of common stock for approximately $43 million, representing an average price of $11.26 per share. In addition, in July 2024, Talos's Board of Directors authorized an additional $150 million for its existing common stock repurchase program.

Monument Discovery: Recently, Talos agreed to acquire a 21.4% W.I. in Monument, a large Wilcox oil discovery located in Walker Ridge blocks 271, 272, 315, and 316, for a purchase price of $32 million as of the effective date. Monument will be developed as a subsea tie-back to the Shenandoah production facility in Walker Ridge. The Monument discovery is post-FID with appraised proved plus probable gross reserves of approximately 115 million barrels of oil equivalent. First production is expected between 20 – 30 MBoe/d gross by late 2026 under restricted flow due to facility rate-constraints. The proved and probable PV-10 of Monument's reserves is valued at approximately $265 million(1). There is an additional 25 – 35 MMBoe drilling location adjacent to the discovery that could extend the resource and Talos's pipeline of drill-ready opportunities. Talos expects a net investment of approximately $25 million in 2024 and approximately $160 million over 2025 and 2026, with no changes to its 2024 capital expenditures guidance. Talos strategically reallocated a portion of its 2024 capital investments for the Monument discovery, given the later-than-anticipated arrival of the West Vela rig. Other partners include Beacon as operator with 30.0% W.I., Navitas Petroleum 28.6% W.I., and Repsol E&P USA Inc. 20.0% W.I.

QuarterNorth Integration Complete: Operational and organizational integration is complete for the QuarterNorth acquisition that closed in March 2024, and we increased expected synergies to $35 million. Talos expects to fully realize projected synergies from the combination by year-end 2024.

Production Updates:

Katmai: Talos expects to take possession of the Seadrill-owned drillship West Vela and commence drilling the Katmai West #2 well in the late third quarter 2024 to further appraise the field, potentially adding significant reserves. Talos projects achieving first production from the Katmai West #2 well in the second quarter 2025. Modifications to the facility, Tarantula, will increase capacity from 27 MBoe/d to 35 MBoe/d. The Katmai wells will be rate-constrained under the upgraded capacity allowing for extended flat-to-low decline production from the facility. Talos will hold 50% W.I. and Ridgewood Energy 50% in Katmai. Talos is the 100% owner and operator of the Tarantula facility.

Sunspear Completion: Talos is in the final stages of securing a rig contract to complete the Sunspear discovery. The Sunspear well, successfully drilled in July 2023, is expected to commence first production during the second quarter 2025, with production flowing to the Prince platform. Partners are Talos 48.0% W.I., an entity managed by Ridgewood Energy Corporation 47.5% W.I., and Houston Energy 4.5% W.I.

Lobster Waterflood: In the second quarter 2024, Talos completed the waterflood (down-hole water injection) well in the Lobster Field, which Talos successfully drilled in the first quarter of 2024. The well began injecting water into the BUL-1 sand at 7,000 barrels of water per day in May 2024. Production is expected to increase by over 2 MBoe/d gross in the next 12-18 months. Talos owns 67% W.I., and Chevron owns 33% W.I.

Exploitation and Exploration Updates:

Ewing Bank 953: Talos is currently drilling the Walter-operated amplitude-supported exploitation well in Ewing Bank 953. The Ewing Bank 953 well targets a Pliocene age reservoir at approximately 19,000 feet with an estimated gross resource potential of 15 – 25 million barrels of oil equivalent, with results expected by the end of the third quarter 2024. Talos holds 33.3% W.I., with Walter Oil & Gas holding 56.7% W.I. and Gordy Oil holding 10% W.I.

Daenerys: Talos expects to utilize the West Vela drillship to drill the Daenerys exploration well subsequent to the Katmai West #2 well. The Daenerys well is a high-impact subsalt project that will evaluate the regionally prolific Middle and Lower Miocene section and carries an estimated gross resource potential between 100 – 300 MMBoe. The prospect is part of a broader farm-in transaction executed in 2023 with a combined approximately 23,000 gross acres in the Walker Ridge area. The well is expected to spud in the first quarter 2025 after drilling Katmai West #2. Talos holds a 27% W.I. Partners include Red Willow, Houston Energy, and Cathexis.

Helms Deep: Talos expects to mobilize the West Vela drillship to Helms Deep after completing drilling operations at Daenerys. The West Vela is set to commence drilling at Helms Deep, an amplitude-supported, near-infrastructure subsalt Pliocene exploitation well, in the third quarter 2025. The Helms Deep well has a proposed depth of approximately 18,000 feet and an estimated gross resource potential between 17 - 27 MMBoe. Talos is targeting 50% W.I.

HP-I Update:

HP-I Resumed Production: In mid-June 2024, the HP-I vessel resumed production ahead of schedule following the completion of the planned regulatory required dry-dock maintenance. The dry-dock period was 52 days and resulted in an estimated deferred production of approximately 4.8 MBoe/d in the second quarter 2024.



(1)

Proved and probable reserves are estimated by Netherland, Sewell & Associates, Inc. ('NSAI"). PV-10 utilizes SEC pricing of $78.21 / BBL WTI and $2.64 per MCF per MMBTU.

SECOND QUARTER  2024 RESULTS

Key Financial Highlights:

($ thousands, except per share and per Boe amounts)

Three Months Ended
June 30, 2024


Total revenues

$

549,165


Net Income (Loss)

$

12,381


Net Income (Loss) per diluted share

$

0.07


Adjusted Net Income (Loss)*

$

5,179


Adjusted Net Income (Loss) per diluted share*

$

0.03


Adjusted EBITDA*

$

343,984


Adjusted EBITDA excluding hedges*

$

361,502


Capital Expenditures

$

122,812


Production

Production for the second quarter 2024 was 95.5 MBoe/d and was 73% oil and 81% liquids.


Three Months Ended
June 30, 2024


Oil (MBbl/d)


69.3


Natural Gas (MMcf/d)


110.8


NGL (MBbl/d)


7.7


Total average net daily (MBoe/d)


95.5


 


Three Months Ended
June 30, 2024



Production


% Oil


% Liquids


% Operated


Green Canyon Area


31.9



79

%


86

%


44

%

Mississippi Canyon Area


50.0



75

%


83

%


77

%

Shelf and Gulf Coast


13.5



49

%


59

%


61

%

Total average net daily (MBoe/d)


95.5



73

%


81

%


64

%

 


Three Months Ended
June 30, 2024


Average realized prices (excluding hedges)



Oil ($/Bbl)

$

80.50


Natural Gas ($/Mcf)

$

2.59


NGL ($/Bbl)

$

22.33


Average realized price ($/Boe)

$

63.22





Average NYMEX prices



WTI ($/Bbl)

$

80.66


Henry Hub ($/MMBtu)

$

2.06


Lease Operating & General and Administrative Expenses

Total lease operating expenses for the second quarter 2024, inclusive of workover, maintenance and insurance costs, were $157.3 million, or $18.11 per Boe. Excluding workover expenses, total lease operating expenses were $148.4 million, or $17.09 per Boe. Lease operating expenses were $16.27 per Boe, adjusting for workover expenses and the impact of the HP-I during the second quarter 2024.

General and Administrative expenses for the second quarter, adjusted to exclude one-time transaction-related costs and non-cash equity-based compensation, were $35.6 million, or $4.10 per Boe. Talos expects General and Administrative expenses to be significantly lower in the second half of 2024, due to the realization of projected synergies.

($ thousands, except per Boe amounts)

Three Months Ended
June 30, 2024


Lease Operating Expenses

$

157,310


Lease Operating Expenses per Boe

$

18.11


Lease Operating Expenses excluding workover

$

148,410


Lease Operating Expenses excluding workover per Boe

$

17.09


Adjusted General & Administrative Expenses*

$

35,600


Adjusted General & Administrative Expenses per Boe*

$

4.10


Capital Expenditures

Capital expenditures for the second quarter 2024, excluding plugging and abandonment and settled decommissioning obligations, totaled $122.8 million.

($ thousands)

Three Months Ended
June 30, 2024


U.S. drilling & completions

$

71,265


Asset management(1)


36,726


Seismic and G&G, land, capitalized G&A and other


14,821


Total Capital Expenditures

$

122,812


____________________

(1)

Asset management consists of capital expenditures for development-related activities primarily associated with recompletions and improvements to our facilities and infrastructure.

Plugging & Abandonment Expenses

Capital expenditures for plugging and abandonment and settled decommissioning obligations for the second quarter 2024 totaled $22.0 million.


Three Months Ended
June 30, 2024


Plugging & Abandonment and Decommissioning Obligations Settled(1)

$

22,044






____________________ 

(1)

Settlement of decommissioning obligations as a result of working interest partners or counterparties of divestiture transactions that were unable to perform the required abandonment obligations due to bankruptcy or insolvency.

Liquidity and Leverage

At June 30, 2024, Talos had approximately $738.7 million of liquidity, with $740.0 million undrawn on its credit facility and approximately $37.8 million in cash, less approximately $39.1 million in outstanding letters of credit. On June 30, 2024, Talos had $1,475.0 million in total debt. Net Debt* was $1,437.2 million. Net Debt to Pro Forma Last Twelve Months ("LTM") Adjusted EBITDA* was 1.0x.

OPERATIONAL & FINANCIAL GUIDANCE UPDATES

For the third quarter 2024, Talos expects average daily production of 92.0 - 97.0 MBoe/d (71% oil).

Talos's reiterates its full year 2024 operational and financial guidance and continues to expect average daily production of 89.0 - 95.0 MBoe/d (71% oil).

Talos expects to generate Free Cash Flow in the second half 2024 in excess of its Credit Facility balance, and is targeting a long-term leverage ratio below 1.0x.

The following summarizes Talos's previously disclosed full-year 2024 operational and production guidance.



FY 2024


($ Millions, unless highlighted):


Low


High


Production

Oil (MMBbl)


23.4



24.7



Natural Gas (Mcf)


40.0



44.2



NGL (MMBbl)


2.5



2.7



Total Production (MMBoe)


32.6



34.8



Avg Daily Production (MBoe/d)


89.0



95.0


Cash Expenses

Cash Operating Expenses and Workovers(1)(2)(4)*

$

555


$

585



G&A(2)(3)*

$

100


$

110


Capex

Capital Expenditures(5)

$

570


$

600


P&A Expenditures

P&A, Decommissioning

$

90


$

100


Interest

Interest Expense(6)

$

175


$

185



(1)

Includes Lease Operating Expenses and Maintenance. 

(2)

Includes insurance costs.

(3)

Excludes non-cash equity-based compensation and transaction and other expenses.

(4)

Includes reimbursements under production handling agreements.

(5)

Excludes acquisitions.

(6)

Includes cash interest expense on debt and finance lease, surety charges and amortization of deferred financing costs and original issue discounts.



*Due to the forward-looking nature a reconciliation of Cash Operating Expenses and G&A to the most directly comparable GAAP measure could not reconciled without unreasonable efforts.

HEDGES

The following table reflects contracted volumes and weighted average prices the Company will receive under the terms of its derivative contracts as of August 6, 2024. The table includes derivative instruments assumed as part of the QuarterNorth acquisition:


Instrument Type

Avg. Daily
Volume


W.A. Swap


W.A. Sub-Floor


W.A. Floor


W.A. Ceiling


Crude – WTI


(Bbls)


(Per Bbl)


(Per Bbl)


(Per Bbl)


(Per Bbl)


July - September 2024

Fixed Swaps


39,696


$

76.75


---


---


---



Collar


1,000


---


---


$

70.00


$

75.00



Long Puts


4,000


---


---


$

70.00


---



Short Puts


1,000


---


$

60.00


---


---


October - December 2024

Fixed Swaps


38,674


$

76.07


---


---


---



Collar


1,000


---


---


$

70.00


$

75.00



Long Puts


4,000


---


---


$

70.00


---



Short Puts


1,000


---


$

60.00


---


---


January - March 2025

Fixed Swaps


32,000


$

72.52


---


---


---



Collar


3,000


---


---


$

65.00


$

84.35


April - June 2025

Fixed Swaps


32,000


$

73.80


---


---


---


July - September 2025

Fixed Swaps


14,000


$

74.04


---


---


---


October - December 2025

Fixed Swaps


14,000


$

73.93


---


---


---














Natural Gas – HH NYMEX


(MMBtu)


(Per MMBtu)


(Per MMBtu)


(Per MMBtu)


(Per MMBtu)


July - September 2024

Fixed Swaps


30,000


$

2.82


---


---


---



Collar


10,000


---


---


$

4.00


$

6.90



Long Puts


13,660


---


---


$

2.90


---


October - December 2024

Fixed Swaps


35,000


$

2.85


---


---


---



Collar


10,000


---


---


$

4.00


$

6.90



Long Puts


13,660


---


---


$

2.90


---


January - March 2025

Fixed Swaps


60,000


$

3.68


---


---


---


April - June 2025

Fixed Swaps


55,000


$

3.38


---


---


---


July - September 2025

Fixed Swaps


30,000


$

3.58


---


---


---


October - December 2025

Fixed Swaps


30,000


$

3.58


---


---


---


CONFERENCE CALL AND WEBCAST INFORMATION

Talos will host a conference call, which will be broadcast live over the internet, on Thursday, August 8, 2024 at 10:00 AM Eastern Time (9:00 AM Central Time). Listeners can access the conference call through a webcast link on the Company's website at: https://www.talosenergy.com/investor-relations/events-calendar/default.aspx. Alternatively, the conference call can be accessed by dialing (800) 836-8184 (North American toll-free) or (646) 357-8785 (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 until August 15, 2024 and can be accessed by dialing (888) 660-6345 and using access code 62299#. For more information, please refer to the Second Quarter 2024 Earnings Presentation available under Presentations and Filings on the Investor Relations section of Talos's website.

ABOUT TALOS ENERGY

Talos Energy (NYSE: TALO) is a technically driven, innovative, independent energy company focused on maximizing long-term value through its Upstream Exploration & Production business in the United States Gulf of Mexico and offshore Mexico. We leverage decades of technical and offshore operational expertise to acquire, explore, and produce assets in key geological trends while maintaining a focus on safe and efficient operations, environmental responsibility, and community impact. For more information, visit www.talosenergy.com.

INVESTOR RELATIONS CONTACT

Clay Jeansonne
[email protected]

CAUTIONARY STATEMENT ABOUT FORWARD-LOOKING STATEMENT

The information in this communication includes "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 (the "Exchange Act"). 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 "will," "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. Forward-looking statements are based on management's current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events. These forward-looking statements are based on our current beliefs, based on currently available information, as to the outcome and timing of future events. Forward-looking statements may include statements about: business strategy; recoverable resources and reserves; drilling prospects, inventories, projects and programs; our ability to replace the reserves that we produce through drilling and property acquisitions; financial strategy, liquidity and capital required for our development program and other capital expenditures; realized oil and natural gas prices; risks related to future mergers and acquisitions and/or to realize the expected benefits of any such transaction timing and amount of future production of oil, natural gas and NGLs; our hedging strategy and results; future drilling plans; availability of pipeline connections on economic terms; competition, government regulations, including financial assurance requirements, and legislative and political developments; our ability to obtain permits and governmental approvals; pending legal, governmental or environmental matters; our marketing of oil, natural gas and NGLs; our integration of acquisitions, including the QuarterNorth acquisition, and the anticipated performance of the combined company; future leasehold or business acquisitions on desired terms; costs of developing properties; general economic conditions, including the impact of continued inflation and associated changes in monetary policy; political and economic conditions and events in foreign oil, natural gas and NGL producing countries and acts of terrorism or sabotage; credit markets; volatility in the political, legal and regulatory environments ahead of the upcoming domestic and foreign presidential elections; estimates of future income taxes; our estimates and forecasts of the timing, number, profitability and other results of wells we expect to drill and other exploration activities; our ongoing strategy with respect to our Zama asset; uncertainty regarding our future operating results and our future revenues and expenses; impact of new accounting pronouncements on earnings in future periods; and plans, objectives, expectations and intentions contained in this communication that are not historical.  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; global demand for oil and natural gas; the ability or willingness of OPEC and other state-controlled oil companies to set and maintain oil production levels and the impact of any such actions; the lack of a resolution to the war in Ukraine and increasing hostilities in the Middle East, and their impact on commodity markets; the impact of any pandemic, and governmental measures related thereto; lack of transportation and storage capacity as a result of oversupply, government and regulations; the effect of a possible U.S. government shutdown and resulting impact on economic conditions and delays in regulatory and permitting approvals; lack of availability of drilling and production equipment and services; adverse weather events, including tropical storms, hurricanes, winter storms and loop currents; cybersecurity threats; sustained inflation and the impact of central bank policy in response thereto; environmental risks; failure to find, acquire or gain access to other discoveries and prospects or to successfully develop and produce from our current discoveries and prospects; geologic risk; drilling and other operating risks; well control risk; regulatory changes, including the impact of financial assurance requirements; 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 competitive responses to our acquisitions and other transactions; the possibility that the anticipated benefits of our acquisitions are not realized when expected or at all, including as a result of the impact of, or problems arising from, the integration of acquired assets and operations; and the other risks discussed in "Risk Factors" of our Annual Report on Form 10-K for the year ended December 31, 2023 and Part II, Item 1A. "Risk Factors" of our Quarterly Report on Form 10-Q for the quarter ended March 31, 2024, each filed with the SEC.  Should one or more of the risks or uncertainties described herein 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, included in this communication 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, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this communication.

PRODUCTION ESTIMATES

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, marketing and storage of oil and gas are subject to disruption due to transportation, processing and storage availability, mechanical failure, human error, adverse weather conditions such as hurricanes, global political and macroeconomic events 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.

RESERVE INFORMATION

Reserve engineering is a process of estimating underground accumulations of oil, natural gas and NGLs that cannot be measured in an exact way. The accuracy of any reserve estimate depends on the quality of available data, the interpretation of such data and price and cost assumptions made by reserve engineers. In addition, the results of drilling, testing and production activities may justify upward or downward revisions of estimates that were made previously. If significant, such revisions would change the schedule of any further production and development drilling. Accordingly, reserve estimates may differ significantly from the quantities of oil, natural gas and NGLs that are ultimately recovered. In addition, we use the terms "gross unrisked recoverable resource potential," "gross reserves," and "reserve potential" in this release, which are not measures of "reserves" prepared in accordance with SEC guidelines or permitted to be included in SEC filings. These resource estimates are inherently more uncertain than estimates of proved reserves or other reserves prepared in accordance with SEC guidelines.

USE OF NON-GAAP FINANCIAL MEASURES 

This release includes the use of certain measures that have not been calculated in accordance with U.S. generally acceptable accounting principles (GAAP) such as, but not limited to, EBITDA, Adjusted EBITDA, LTM Adjusted EBITDA, Pro Forma LTM Adjusted EBITDA, Net Debt, Net Debt to LTM Adjusted EBITDA, Net Debt to Pro Forma LTM Adjusted EBITDA, Adjusted Free Cash Flow and Leverage, Adjusted EBITDA excluding hedges. Non-GAAP financial measures have limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our results as reported under GAAP. Reconciliations for non-GAAP measure to GAAP measures are included at the end of this release.

Talos Energy Inc.

Consolidated Balance Sheets

(In thousands, except share amounts)



June 30, 2024


December 31, 2023



(Unaudited)




ASSETS





Current assets:





Cash and cash equivalents

$

37,797


$

33,637


Accounts receivable:





Trade, net


243,826



178,977


Joint interest, net


156,287



79,337


Other, net


13,468



19,296


Assets from price risk management activities


16,412



36,152


Prepaid assets


79,870



64,387


Other current assets


18,123



10,389


Total current assets


565,783



422,175


Property and equipment:





Proved properties


9,435,902



7,906,295


Unproved properties, not subject to amortization


653,143



268,315


Other property and equipment


34,824



34,027


Total property and equipment


10,123,869



8,208,637


Accumulated depreciation, depletion and amortization


(4,643,062)



(4,168,328)


Total property and equipment, net


5,480,807



4,040,309


Other long-term assets:





Restricted cash


104,368



102,362


Assets from price risk management activities


2,784



17,551


Equity method investments


109,688



146,049


Other well equipment


62,991



54,277


Notes receivable, net


17,041



16,207


Operating lease assets


12,429



11,418


Other assets


5,964



5,961


Total assets

$

6,361,855


$

4,816,309


LIABILITIES AND STOCKHOLDERS? EQUITY





Current liabilities:





Accounts payable

$

91,871


$

84,193


Accrued liabilities


315,191



227,690


Accrued royalties


84,126



55,051


Current portion of long-term debt




33,060


Current portion of asset retirement obligations


78,765



77,581


Liabilities from price risk management activities


51,607



7,305


Accrued interest payable


48,970



42,300


Current portion of operating lease liabilities


3,928



2,666


Other current liabilities


37,181



48,769


Total current liabilities


711,639



578,615


Long-term liabilities:





Long-term debt


1,435,899



992,614


Asset retirement obligations


1,080,082



819,645


Liabilities from price risk management activities


1,441



795


Operating lease liabilities


17,332



18,211


Other long-term liabilities


389,137



251,278


Total liabilities


3,635,530



2,661,158


Commitments and contingencies





Stockholders? equity:





Preferred stock; $0.01 par value; 30,000,000 shares authorized and zero shares issued or outstanding
as of June 30, 2024 and December 31, 2023, respectively





Common stock; $0.01 par value; 270,000,000 shares authorized; 187,339,187 and 127,480,361
shares issued as of June 30, 2024 and December 31, 2023, respectively


1,873



1,275


Additional paid-in capital


3,262,700



2,549,097


Accumulated deficit


(447,775)



(347,717)


Treasury stock, at cost; 7,204,380 and 3,400,000 shares as of June 30, 2024 and December 31, 2023,
respectively


(90,473)



(47,504)


Total stockholders? equity


2,726,325



2,155,151


Total liabilities and stockholders? equity

$

6,361,855


$

4,816,309


 

Talos Energy Inc.

Consolidated Statements of Operations

(In thousands, except per share amounts)

(Unaudited)



Three Months Ended June 30,


Six Months Ended June 30,



2024


2023


2024


2023


Revenues:









Oil

$

507,408


$

342,983


$

900,629


$

635,677


Natural gas


26,060



16,329



...49,758



36,512


NGL


15,697



7,898



28,710



17,603


Total revenues


549,165



367,210



979,097



689,792


Operating expenses:









Lease operating expense


157,310



101,165



292,488



182,527


Production taxes


476



607



1,020



1,213


Depreciation, depletion and amortization


259,091



169,794



474,755



317,117


Accretion expense


30,732



22,760



57,635



42,174


General and administrative expense


48,247



33,182



118,088



96,369


Other operating (income) expense


(1,061)



(723)



(87,104)



2,115


Total operating expenses


494,795



326,785



856,882



641,515


Operating income (expense)


54,370



40,425



122,215



48,277


Interest expense


(48,982)



(45,632)



(99,827)



(83,213)


Price risk management activities income (expense)


2,302



26,197



(84,760)



85,134


Equity method investment income (expense)


(456)



(2,012)



(8,510)



5,431


Other income (expense)


4,164



1,591



(51,732)



8,257


Net income (loss) before income taxes


11,398



20,569



(122,614)



63,886


Income tax benefit (expense)


983



(6,892)



22,556



39,651


Net income (loss)

$

12,381


$

13,677


$

(100,058)


$

103,537











Net income (loss) per common share:









Basic

$

0.07


$

0.11


$

(0.59)


$

0.90


Diluted

$

0.07


$

0.11


$

(0.59)


$

0.89


Weighted average common shares outstanding:









Basic


183,564



125,436



171,027



115,590


Diluted


183,692



125,667



171,027



116,363


 

Talos Energy Inc.

Consolidated Statements of Cash Flows

(In thousands)

(Unaudited)



Six Months Ended June 30,



2024


2023


Cash flows from operating activities:





Net income (loss)

$

(100,058)


$

103,537


Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:





Depreciation, depletion, amortization and accretion expense


532,390



359,291


Amortization of deferred financing costs and original issue discount


5,084



7,629


Equity-based compensation expense


5,544



8,687


Price risk management activities (income) expense


84,760



(85,134)


Net cash received (paid) on settled derivative instruments


(21,012)



(4,161)


Equity method investment (income) expense


8,510



(5,431)


Loss (gain) on extinguishment of debt


60,256




Settlement of asset retirement obligations


(50,128)



(47,683)


Loss (gain) on sale of assets


(2,500)




Loss (gain) on sale of business


(86,940)




Changes in operating assets and liabilities:





Accounts receivable


3,076



35,127


Other current assets


(5,150)



(23,790)


Accounts payable


(43,608)



(3,890)


Other current liabilities


17,748



(22,975)


Other non-current assets and liabilities, net


(22,182)



(44,124)


Net cash provided by (used in) operating activities


385,790



277,083


Cash flows from investing activities:





Exploration, development and other capital expenditures


(269,170)



(298,658)


Cash acquired in excess of payments for acquisitions




17,617


Payments for acquisitions, net of cash acquired


(916,045)




Proceeds from (cash paid for) sale of property and equipment, net




(8,488)


Contributions to equity method investees


(19,627)



(15,260)


Investment in intangible assets




(7,796)


Proceeds from sales of businesses


141,997




Net cash provided by (used in) investing activities


(1,062,845)



(312,585)


Cash flows from financing activities:





Issuance of common stock


387,717




Issuance of senior notes


1,250,000




Redemption of senior notes


(897,116)



(15,000)


Proceeds from Bank Credit Facility


770,000



505,000


Repayment of Bank Credit Facility


(745,000)



(305,000)


Deferred financing costs


(27,386)



(11,775)


Other deferred payments


(1,234)



(462)


Payments of finance lease


(8,747)



(8,026)


Purchase of treasury stock


(39,326)



(47,504)


Employee stock awards tax withholdings


(5,687)



(7,378)


Net cash provided by (used in) financing activities


683,221



109,855







Net increase (decrease) in cash, cash equivalents and restricted cash


6,166



74,353


Cash, cash equivalents and restricted cash:





Balance, beginning of period


135,999



44,145


Balance, end of period

$

142,165


$

118,498







Supplemental non-cash transactions:





Capital expenditures included in accounts payable and accrued liabilities

$

79,832


$

113,319


Supplemental cash flow information:





Interest paid, net of amounts capitalized

$

64,452


$

63,492


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 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 General and Administrative Expenses to Adjusted General and Administrative Expenses

We believe the presentation of Adjusted General and Administrative Expenses provides 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 General & Administrative Expenses has limitations as an analytical tool and should not be considered in isolation or as substitutes for analysis of our results as reported under GAAP or as alternatives to net income (loss), operating income (loss) or any other measure of financial performance presented in accordance with GAAP. We define these as the following:

General and Administrative Expenses. General and Administrative Expenses generally consist of costs incurred for overhead, including payroll and benefits for our corporate staff, costs of maintaining our headquarters, costs of managing our production operations, bad debt expense, equity-based compensation expense, audit and other fees for professional services and legal compliance. A portion of these expenses are allocated based on the percentage of employees dedicated to each operating segment.

($ thousands)

Three Months Ended
June 30, 2024


Reconciliation of General & Administrative Expenses to Adjusted General & Administrative Expenses:



Total General and administrative expense

$

48,247


Transaction and other expenses(1)


(9,857)


Non-cash equity-based compensation expense


(2,790)


Adjusted General & Administrative Expenses

$

35,600


____________________

(1)

Transaction expenses includes $9.3 million in costs related to the QuarterNorth acquisition, inclusive of $8.1 million in severance expense for the three months ended June 30, 2024.

Reconciliation of Net Income (Loss) to EBITDA and Adjusted EBITDA

"EBITDA" and "Adjusted EBITDA" 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. EBITDA and Adjusted EBITDA have limitations as analytical tools and should not be considered in isolation or as substitutes for analysis of our results as reported under GAAP or as alternatives to net income (loss), operating income (loss) or any other measure of financial performance presented in accordance with GAAP. We define these as the following:

EBITDA. Net income (loss) plus interest expense; income tax expense (benefit); depreciation, depletion and amortization; and accretion expense.

Adjusted EBITDA. EBITDA plus non-cash write-down of oil and natural gas properties, transaction and other (income) expenses, decommissioning obligations, derivative fair value (gain) loss, net cash receipts (payments) on settled derivatives, (gain) loss on debt extinguishment, non-cash write-down of other well equipment and non-cash equity-based compensation expense.

Adjusted EBITDA excluding hedges. We have historically provided as a supplement to—rather than in lieu of—Adjusted EBITDA including hedges, provides useful information regarding our results of operations and profitability by illustrating the operating results of our oil and natural gas properties without the benefit or detriment, as applicable, of our financial oil and natural gas hedges. By excluding our oil and natural gas hedges, we are able to convey actual operating results using realized market prices during the period, thereby providing analysts and investors with additional information they can use to evaluate the impacts of our hedging strategies over time.

The following tables present a reconciliation of the GAAP financial measure of Net Income (loss) to EBITDA, Adjusted EBITDA, Adjusted EBITDA excluding hedges for each of the periods indicated (in thousands):


Three Months Ended


($ thousands)

June 30,
2024


March 31,
2024(4)


December 31,
2023(4)


September 30,
2023(4)


Reconciliation of Net Income (Loss) to Adjusted EBITDA:









Net Income (loss)

$

12,381


$

(112,439)


$

85,898


$

(2,103)


Interest expense


48,982



50,845



44,295



45,637


Income tax expense (benefit)


(983)



(21,573)



(5,081)



(15,865)


Depreciation, depletion and amortization


259,091



215,664



183,058



163,359


Accretion expense


30,732



26,903



22,722



21,256


EBITDA


350,203



159,400



330,892



212,284


Transaction and other (income) expenses(1)


6,629



(49,157)



5,504



(64,321)


Decommissioning obligations(2)


4,182



855



2,425



7,972


Derivative fair value (gain) loss(3)


(2,302)



87,062



(94,596)



98,802


Net cash received (paid) on settled derivative instruments(3)


(17,518)



(3,494)



1,017



(6,313)


Loss on extinguishment of debt




60,256






Non-cash equity-based compensation expense


2,790



2,754



3,873



393


Adjusted EBITDA


343,984



257,676



249,115



248,817


Add: Net cash (received) paid on settled derivative instruments(3)


17,518



3,494



(1,017)



6,313


Adjusted EBITDA excluding hedges

$

361,502


$

261,170


$

248,098


$

255,130


____________________

(1)

Transaction expenses includes $9.3 million in costs related to the QuarterNorth acquisition, inclusive of $8.1 million in severance expense for the three months ended June 30, 2024, $28.1 million in costs related to the QuarterNorth acquisition, inclusive of $14.2 million in severance expense and $9.8 million in costs related to the divestiture of TLCS, inclusive of $3.7 million in severance expense for the three months ended March 31, 2024, $0.9 million in costs related to the EnVen Energy Corporation ("EnVen") Acquisition, inclusive of $0.5 million in severance expense for the three months ended December 31, 2023 and $1.5 million in costs related to the EnVen Acquisition, inclusive of $0.9 million in severance expense for the three months ended September 30, 2023. Other income (expense) includes restructuring expenses, cost saving initiatives and other miscellaneous income and expenses that we do not view as a meaningful indicator of our operating performance. For the three months ended March 31, 2024, the amount includes a gain of $86.9 million related to the divestiture of TLCS. For the three months ended September 30, 2023, the amount includes a $66.2 million gain on the divestiture of 49.9% equity interest in our subsidiary, Talos Energy Mexico 7, S. de R.L. de C.V. to Zamajal, S.A. de C.V., a wholly owned subsidiary of Grupo Carso.

(2)

Estimated decommissioning obligations were a result of working interest partners or counterparties of divestiture transactions that were unable to perform the required abandonment obligations due to bankruptcy or insolvency and are included in "Other operating (income) expense" on our consolidated statements of operations.

(3)

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 an unrealized basis during the period the derivatives settled.

(4)

Reporting period includes Carbon Capture & Sequestration ("CCS") business.

Reconciliation of Adjusted EBITDA to Adjusted Free Cash Flow and Reconciliation of Net Cash Provided by Operating Activities to Adjusted Free Cash Flow

"Adjusted Free Cash Flow" before changes in working capital provides 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 Free Cash Flow has limitations as an analytical tool and should not be considered in isolation or as substitutes for analysis of our results as reported under GAAP or as alternatives to net income (loss), operating income (loss) or any other measure of financial performance presented in accordance with GAAP. We define these as the following:

Capital Expenditures and Plugging & Abandonment. Actual capital expenditures and plugging & abandonment recognized in the quarter, inclusive of accruals.

Interest Expense. Actual interest expense per the income statement.

Talos did not pay any cash income taxes in the period, therefore cash income taxes have no impact to the reported Adjusted Free Cash Flow before changes in working capital number.

 

 

($ thousands)

Three Months Ended
June 30, 2024


Reconciliation of Adjusted EBITDA to Adjusted Free Cash Flow (before changes in working capital):



Adjusted EBITDA

$

343,984


Capital expenditures


(122,812)


Plugging & abandonment


(22,221)


Decommissioning obligations settled


178


Investment in Mexico


(2,108)


Interest expense


(48,982)


Adjusted Free Cash Flow (before changes in working capital)


148,039



($ thousands)

Three Months Ended
June 30, 2024


Reconciliation of Net Cash Provided by Operating Activities to Adjusted Free Cash Flow (before
changes in working capital):



Net cash provided by operating activities(1)

$

289,364


(Increase) decrease in operating assets and liabilities


(25,969)


Capital expenditures(2)


(122,813)


Decommissioning obligations settled


178


Investment in Mexico


(2,108)


Transaction and other (income) expenses(3)


9,129


Decommissioning obligations(4)


4,182


Amortization of deferred financing costs and original issue discount


(2,486)


Income tax benefit


(983)


Other adjustments


(455)


Adjusted Free Cash Flow (before changes in working capital)


148,039


________________________

(1)

Includes settlement of asset retirement obligations.

(2)

Includes accruals and excludes acquisitions.

(3)

Transaction expenses includes $9.3 million in costs related to the QuarterNorth acquisition, inclusive of $8.1 million in severance expense for the three months ended June 30, 2024. Other income (expense) includes restructuring expenses, cost saving initiatives and other miscellaneous income and expenses that we do not view as a meaningful indicator of our operating performance.

(4)

Estimated decommissioning obligations were a result of working interest partners or counterparties of divestiture transactions that were unable to perform the required abandonment obligations due to bankruptcy or insolvency.

Reconciliation of Net Income to Adjusted Net Income (Loss) and Adjusted Earnings per Share

"Adjusted Net Income (Loss)" and "Adjusted Earnings per Share" are 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 (Loss) and Adjusted Earnings per Share have limitations as analytical tools 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), earnings per share or any other measure of financial performance presented in accordance with GAAP.

Adjusted Net Income (Loss). Net income (loss) plus accretion expense, transaction related costs, derivative fair value (gain) loss, net cash receipts (payments) on settled derivative instruments and non-cash equity-based compensation expense.

Adjusted Earnings per Share. Adjusted Net Income (Loss) divided by the number of common shares.


Three Months Ended June 30, 2024


($ thousands, except per share amounts)



Basic per Share


Diluted per Share


Reconciliation of Net Income (Loss) to Adjusted Net Income (Loss):







Net Income (loss)

$

12,381


$

0.07


$

0.07


Transaction and other (income) expenses(1)


6,629


$

0.04


$

0.04


Decommissioning obligations(2)


4,182


$

0.02


$

0.02


Derivative fair value loss(3)


(2,302)


$

(0.01)


$

(0.01)


Net cash received on paid derivative instruments(3)


(17,518)


$

(0.10)


$

(0.10)


Non-cash income tax benefit


(983)


$

(0.01)


$

(0.01)


Loss on extinguishment of debt



$


$


Non-cash equity-based compensation expense


2,790


$

0.02


$

0.02


Adjusted Net Income (Loss)(4)

$

5,179


$

0.03


$

0.03









Weighted average common shares outstanding at June 30, 2024:







Basic


183,564






Diluted


183,692






 ____________________

(1)

Transaction expenses includes $9.3 million in costs related to the QuarterNorth acquisition, inclusive of $8.1 million in severance expense for the three months ended June 30, 2024.

(2)

Estimated decommissioning obligations were a result of working interest partners or counterparties of divestiture transactions that were unable to perform the required abandonment obligations due to bankruptcy or insolvency.

(3)

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 Net Income (Loss) on an unrealized basis during the period the derivatives settled.

(4)

The per share impacts reflected in this table were calculated independently and may not sum to total adjusted basic and diluted EPS due to rounding.

Reconciliation of Total Debt to Net Debt and Net Debt to LTM Adjusted EBITDA

We believe the presentation of Net Debt, LTM Adjusted EBITDA, Net Debt to LTM Adjusted EBITDA and Net Debt to Pro Forma 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.

Net Debt. Total Debt principal minus cash and cash equivalents.

Net Debt to LTM Adjusted EBITDA. Net Debt divided by the LTM Adjusted EBITDA.

($ thousands)

June 30, 2024


Reconciliation of Net Debt:



9.000% Second-Priority Senior Secured Notes – due February 2029

$

625,000


9.375% Second-Priority Senior Secured Notes – due February 2031


625,000


Bank Credit Facility – matures March 2027


225,000


Total Debt


1,475,000


Less: Cash and cash equivalents


(37,797)


Net Debt

$

1,437,203





Calculation of LTM Adjusted EBITDA:



Adjusted EBITDA for three months period ended September 30, 2023

$

248,817


Adjusted EBITDA for three months period ended December 31, 2023


249,115


Adjusted EBITDA for three months period ended March 31, 2024


257,676


Adjusted EBITDA for three months period ended June 30, 2024


343,984


LTM Adjusted EBITDA

$

1,099,592





Acquired Assets Adjusted EBITDA:



Adjusted EBITDA for three months period ended September 30, 2023


161,427


Adjusted EBITDA for three months period ended December 31, 2023


129,063


Adjusted EBITDA for period January 1, 2024 to March 4, 2024


99,490


LTM Adjusted EBITDA from Acquired Assets

$

389,980





Pro Forma LTM Adjusted EBITDA

$

1,489,572





Reconciliation of Net Debt to Pro Forma LTM Adjusted EBITDA:



Net Debt / Pro Forma LTM Adjusted EBITDA(1)

1.0x


 ____________________

(1)

Net Debt / Pro Forma LTM Adjusted EBITDA figure excludes the Finance Lease. Had the Finance Lease been included, Net Debt / Pro Forma LTM Adjusted EBITDA would have been 1.1x.

Cision
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SOURCE Talos Energy