Talos Energy Announces Second Quarter 2020 Financial And Operational Results

HOUSTON, Aug. 5, 2020 /PRNewswire/ -- Talos Energy Inc. ("Talos," or the "Company") (NYSE: TALO) today announced its financial and operational results for the second quarter of 2020.

Key Highlights:

• Production of 52.4 thousand barrels of oil equivalent per day ("MBoe/d"), of which 69% was oil and 76% was liquids. Production for the quarter was impacted by 14.4 MBoe/d of production deferrals associated with voluntary shut-ins, accelerated maintenance, Tropical Storm Cristobal and other miscellaneous items.
• Net Loss of $140.6 million in the quarter, or $2.14 loss per diluted share, and Adjusted Net Loss⁽¹⁾ in the quarter of $29.4 million, or $0.45 adjusted loss per diluted share. Year-to-date, Net Income of $17.1 million, or $0.28 per diluted share, and year-to-date Adjusted Net Loss⁽¹⁾ of $13.8 million, or $0.22 per diluted share.
• Adjusted EBITDA⁽¹⁾ of $97.5 million for the second quarter and Adjusted EBITDA⁽¹⁾ of $245.2 million for the first half of the year.
• Capital expenditures, inclusive of plugging and abandonment costs, of $129.1 million during the quarter. Year-to-date capital expenditures were $202.3 million.
• As of June 30, 2020, proved reserves for the Company totaled 189.5 MMBoe with a PV-10 of $2.8 billion. Additionally, probable reserves were 79.7 MMBoe with a PV-10 of $1.3 billion. Figures are presented pro forma for the recently closed acquisition.
• Eliminated $39.2 million, or approximately 10% of the outstanding balance, of the Company's 11.00% Second Lien Notes.
• On August 5, 2020, closed the acquisition of additional working interests in 16 selected producing properties from affiliates of Castex 2005.
• As of June 30, 2020, maintained a leverage position of 1.4x Net Debt to Credit Facility LTM Adjusted EBITDA⁽¹⁾.
• Over $400.0 million of liquidity from $107.9 million in cash and availability under the Company's $985.0 million borrowing base.

 

(1)

Adjusted Net Loss, Adjusted Loss per Share, Adjusted EBITDA, Adjusted EBITDA Margin, Free Cash Flow, Credit Facility LTM Adjusted EBITDA and Net Debt to LTM 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: "Although the second quarter presented unprecedented challenges for our industry, we took several actions in the quarter that have made us a stronger company for the remainder of this year and beyond, including opportunistically lowering our debt, significantly reducing our costs, adding to our working interest in several producing assets we currently own and deepening our inventory of high impact prospects.

"We successfully completed our Tornado IV project, which will provide additional production from the main producing interval in the near term before we turn the well into a water injection well in early 2021. We are currently on location in our Kaleidoscope and Bulleit projects with first oil expected from both late in the third quarter, establishing a strong foundation for 2021.

"In Mexico, we are making progress on our Zama project by finalizing engineering design while continuing to work with Pemex on unitization as part of the formal instructions to reach an agreement in the next six months. Separately, Netherland, Sewell and Associates completed their review of our Xaxamani discovery in Block 31, providing a "best estimate" of the gross resources in the contract area at over 100.0 MMBoe. Xaxamani is our second major discovery in offshore Mexico and highlights our capabilities to drive exploration success in basins beyond the U.S. Gulf of Mexico."

Duncan continued: "We lowered our capital program in 2020 compared to 2019 and, even with the integration of new assets, we currently expect to complete the year well inside our capital, cash operating and general and administrative expense guidance. Our teams are working tirelessly during a stressful time to keep us on track in realizing these savings. Looking ahead, we expect to exit the year with a production rate between 71.0 – 73.0 MBoe/d, remain free cash flow positive for the year and sustain one of the most competitive credit profiles amongst our peers. We remain focused on continuing to drive down our lifting cost structure while bolstering our deep project inventory and executing on ample business development opportunities to become a more diversified and resilient company."

RECENT DEVELOPMENTS AND OPERATIONS UPDATE

Corporate Activities

• Cost Reduction Initiatives: Talos continues to realize substantial cost reductions across its cash operating, general and administrative and capital expense categories. In total, the Company expects over $200 million in cumulative savings for the full year 2020 from its original financial guidance released in February 2020, which will allow the Company to maintain a positive free cash flow profile for the year despite lower commodity prices and associated shut-ins. Additionally, compared to 2019 on a pro forma basis, Talos expects to reduce general and administrative costs approximately by $20.0 million, or approximately 25%. Cash operating expenses is expected to reduce by approximately $40.0 million, or approximately 12%.
• Debt Exchange Transaction: During the second quarter Talos eliminated $39.2 million of debt, primarily from one exchange transaction that eliminated $37.2 million of its 11.00% Second Lien Notes. The exchange transaction will eliminate future cash interest payments on the Notes of approximately $7.5 million from settlement through maturity.
• Bolt-On Acquisition: On August 5, 2020, Talos closed the value accretive acquisition of additional working interest in 16 selected producing properties from affiliates of Castex Energy 2005. The transaction was valued at PV-20 of PDP, provides strong incremental cash flow and ensures operational control over most of the assets, which the Company already held working interest in. At closing, the Company issued approximately 4.60 million common shares to the sellers, bringing the current outstanding share count to 73.0 million. Talos has entered into several gas hedging contracts accounting for the majority of the PDP volumes associated with the acquired assets through year-end 2022.
• Lease Sale 254: Results of the March 2020 lease sale were recently finalized, with Talos acquiring four Green Canyon area blocks in a joint package bid with affiliates of bp plc. The Company acquired a 25.0% working interest in several sub-salt Miocene prospects in Green Canyon blocks 319, 320, 322 and 363, comprising 23,040 gross or 5,760 net acres, for a net cost of approximately $0.9 million, or $159/acre. As of June 30, 2020, Talos holds approximately 1.4 million gross acres of leasehold in the U.S. Gulf of Mexico (0.7 million net), of which approximately 50% is held by production and 50% is primary term.
• Production Shut-ins: Production deferrals for the quarter totaled approximately 1.3 MMBoe or 14.4 MBoe/d, primarily comprised from non-operated well and facilities shut-ins, Talos accelerated maintenance projects and Tropical Storm Cristobal. Additionally, the company permanently shuttered approximately 0.6 MBoe/d from legacy shallow water properties that had higher operating costs.
• Ram Powell Platform: Production at the Company's Ram Powell facility is currently shut-in for an unplanned riser repair procedure. Talos expects production at the facility to resume in September of 2020 pending the completion and certification of repairs. Prior to the shut-in, Talos's net production from Ram Powell was approximately 4.8 MBoe/d net.
• COVID-19 Response: In response to COVID-19, Talos has continued to take precautionary measures to protect the safety of its employees and contractors as well as to ensure operational continuity. Talos corporate employees are continuing to work from home until further notice regarding formal office location re-openings. The Company has instituted numerous safety procedures and health checks for offshore staff, resulting in zero facility downtime to date due to COVID-19.

Drilling and Exploration Activities – U.S. Gulf of Mexico

• Claiborne: The Claiborne #3 development well and Claiborne #1 recompletion project were finalized in the second quarter and brought online late June, collectively increasing production rates from the field by 13.5 MBoe/d gross, 2.6 MBoe/d net.
• Tornado IV: Drilling operations encountered geological and pressure conditions in line with expectations and logged 87 feet of net pay in the B-6 Upper zone. Talos has finalized the completion of the B-6 Upper zone and expects first production by the end of the third quarter.
• Kaleidoscope: Drilling operations from the Company's Green Canyon 18 facility are ongoing with the first objective expected to be encountered early August. Talos expects to initiate completion activities soon thereafter with first production expected by the end of the third quarter of 2020.
• Bulleit: Following start-up of the Tornado IV well, the rig will mobilize to the Green Canyon 21 Bulleit well and commence completion activities. Tie-in activities to Talos's Green Canyon 18 facility are ongoing in preparation for first production, which is expected by the end of the third quarter of 2020.

Upon completion of these projects by the end of September, the Company's capital investment is expected to be significantly reduced, with the fourth quarter expected to have the lowest level of investment of 2020.

Drilling and Exploration Activities – Mexico

• Block 7: On July 7, 2020, the Company received a notice from Mexico's Ministry of Energy ("SENER") instructing the partners of Block 7 and Petróleos Mexicanos ("Pemex") to unitize the Zama field. The formal notice establishes a firm deadline to advance the unitization process, which is required before a field development plan can be finalized and the partners can reach Final Investment Decision ("FID").
• Block 31: Netherland, Sewell and Associates, Inc. ("NSAI") recently completed an independent resource evaluation of the Xaxamani discovery. NSAI provided a "best estimate" of the gross resources for the asset at over 100.0 MMBoe, with approximately 95% oil. The discovery is located in very shallow waters (approximately 60 feet) and is less than two miles from shore. Talos holds a 25% participation interest in Block 31.

2020 Guidance
Talos expects to exit 2020 with a production rate between 71.0 – 73.0 MBoe/d.

For the full year 2020, the Company expects production at the low end of its previously stated production forecast range of 61.0 – 64.4 MBoe/d primarily due to greater than anticipated second quarter shut-ins across our portfolio and Ram Powell repairs impacting third-quarter production, offset by production from the recently acquired assets.

Talos expects cash operating expenses and general and administrative expenses to be in the lower-end of its previously stated forecast ranges of $275 - $300 million and $57 - $62 million, respectively, for the full year 2020. The full year expectations reflect Talos's progress in realizing operational efficiencies and more appropriately sizing project and corporate staffing for current activity levels. The Company's expectations are inclusive of incremental lease operating expenses and other costs associated with the recently closed acquisition as well as additional expenses associated with operational safety related to COVID-19.

Talos expects capital expenditures to remain in line with its forecast range of $355 - $380 million for the full year 2020.

Mid-Year 2020 Reserves
As of June 30, 2020, Talos had proved reserves of 189.5 MMBoe, with 67.0% oil and 76.0% proved developed, pro forma for the recently closed acquisition. The PV-10 of proved reserves was $2.8 billion. The reserves and associated PV-10 are fully burdened by and net of all plugging & abandonment costs associated with the properties included in the reserves report. The following table summarizes Talos's pro forma proved reserves at June 30, 2020:

	Summary of Pro Forma Proved Reserves
	MBoe	%of Total Proved	Percent Oil	PV-10(1) ($MM)
Proved Developed Producing	93,298	49.2%	69.6%	$1,822
Proved Developed Non-Producing	50,641	26.7%	61.7%	548
Total Proved Developed	143,938	76.0%	66.8%	2,370
Proved Undeveloped	45,527	24.0%	67.4%	450
Total Proved	189,465	100.0%	67.0%	$2,820

In addition to the proved reserves, Talos's pro forma probable reserves at mid-year 2020 were 79.7 MMBoe and had a PV-10 of $1.3 billion.

In accordance with guidelines established by the SEC, the Company's estimated proved reserves as of June 30, 2020 were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average price for each commodity, calculated as the unweighted arithmetic average of the price on the first day of each month for the year end June 30, 2020. The West Texas Intermediate spot price and the Henry Hub spot price were utilized as the referenced price and appropriately adjusted for quality, transportation, fees, energy content and basis differentials. Therefore, the PV-10 of Talos's proved reserves at June 30, 2020 is based on an average crude oil price of $47.17 per barrel and an average natural gas price of $2.07 per MMBtu, prior to being adjusted for quality, transportation, fees, energy content and basis differentials.

FIRST QUARTER 2020 RESULTS

Key Financial Highlights:

	Three Months Ended June 30, 2020
Period results ($ million, except per share and per Boe amounts):
Total Revenues(2) (inclusive of hedges)	$	174.9
Net Loss	$	(140.6)
Loss per diluted share	$	(2.14)
Adjusted Net Loss (1)	$	(29.4)
Adjusted Loss per diluted share(1)	$	(0.45)
Adjusted EBITDA(1)	$	97.5
Capital Expenditures (including Plug & Abandonment)	$	129.1
Adjusted EBITDA Margin(1):
Adjusted EBITDA (% of Revenue, inclusive of hedges)		56	%
Adjusted EBITDA per Boe	$	20.41

Production, Realized Prices and Revenue
Production for the second quarter of 2020 was 4.8 MMBoe, with oil production accounting for 69% of the total. Oil price realizations, net of certain gathering, transportation, quality differentials and other costs, were $22.71 per barrel equivalent, before hedges.

		Three Months Ended June 30, 2020
Production volumes
Oil production volume (MBbls)			3,279
Natural Gas production volume (MMcf)			6,997
NGL production volume (MBbls)			330
Total production volume (MBoe)			4,775
Average net daily production volumes
Oil (MBbl/d)			36.0
Natural Gas (MMcf/d)			76.9
NGL (MBbl/d)			3.6
Total average net daily (MBoe/d)			52.4
Average realized prices (excluding hedges)(3)
Oil ($/Bbl)		$	22.71
Natural Gas ($/MMBtu)			1.59
NGL ($/Bbl)			5.95
Average realized price ($/Boe)			18.34
Average NYMEX prices
WTI ($/Bbl)		$	27.96
Henry Hub ($/MMBtu)		$	1.71
Revenues ($ million)
Oil		$	74.5
Natural Gas			11.1
NGL			2.0
Revenue - Operations		$	87.6
Other revenue			1.3
Total revenue		$	88.9
Net cash receipts (payments) on settled derivative instruments			86.0
Total revenue inclusive of realized impact of hedges		$	$174.9

 

	Three Months Ended June 30, 2020
	Production		% Oil		% Liquids		% Operated
Average net daily production volumes by Core Area (MBoe/d)
Green Canyon Area	12.8		80%		87%		96%
Mississippi Canyon Area	25.0		79%		87%		65%
Shelf and Gulf Coast	14.7		41%		47%		69%
Total average net daily (MBoe/d)	52.4		69%		76%		75%

Expenses
Total lease operating expenses ("LOE"), inclusive of workover and maintenance and insurance costs for the quarter, were $63.9 million or $13.38/Boe. General and administrative expenses ("G&A") for the quarter, excluding stock-based compensation, transaction-related expenses and other one-time time expenses, was $11.3 million, or $2.38/Boe.

		Three Months Ended June 30, 2020				Per Boe
Lease Operating Expenses		$	63.9			$	13.38
General & Administrative Expenses (excluding non-cash and non-recurring items)		$	11.3			$	2.38

Other Financial Metrics
Capital Expenditures & Asset Management Activities
Capital expenditures for the quarter were $129.1 million, inclusive of plugging & abandonment costs.

		Three Months Ended June 30, 2020
Capital Expenditures
U.S. Drilling & Completions		$	90.3
Mexico Appraisal & Exploration			(0.1)
Asset Management			11.4
Seismic and G&G / Land / Capitalized G&A			15.1
Total Capital Expenditures		$	116.9
Plugging & Abandonment			12.2
Total Capital Expenditures and Plugging & Abandonment		$	129.1

Liquidity & Debt
Talos has over $400.0 million of liquidity and as of June 30, 2020, maintained $107.9 million in cash on hand and $650.0 million drawn on the $985.0 million borrowing base under its credit facility. Not included in the liquidity number is an additional $25.0 million the Company could have access to, pending certain lender approvals.

The Company had approximately $1,079 million in total debt, inclusive of $71.2 million related to the HP-I finance lease. Inclusive of eight months contribution from the recent ILX/Castex acquisition, Net Debt to Credit Facility LTM Adjusted EBITDA⁽¹⁾, as determined in accordance with the Company's credit agreement, was 1.4x. Credit Facility LTM Adjusted EBITDA⁽¹⁾ does not include any pro forma impact from the Company's most recently announced acquisition of assets from Castex Energy 2005. Excluding the ILX/Castex contribution, Net Debt to LTM Adjusted EBITDA⁽¹⁾ ratio was 1.7x.

Footnotes:

(1)	Adjusted Net Loss, Adjusted Loss per Share, Adjusted EBITDA, Adjusted EBITDA Margin, Credit Facility LTM Adjusted EBITDA and Net Debt to LTM Adjusted EBITDA are non-GAAP financial measures. See "Supplemental Non-GAAP Information" below for additional detail and reconciliations of GAAP to non-GAAP measures.
(2)	Includes $1.3 million of federal royalty refund.
(3)	Average realized prices are net of certain gathering, transportation, quality differentials and other costs.

HEDGES

The following table reflects the current contracted volumes and weighted average prices the Company will receive under the terms of its derivative contracts, including contracts entered into following the end of the quarter:

		Instrument Type		Avg. Daily Volume		Weighted Avg. Swap Price		Weighted Avg. Put Price		Weighted Avg. Call Price
Crude-WTI				(Bbls)		(Per Bbl)		(Per Bbl)		(Per Bbl)
July - December 2020		Swaps		30,674		$44.45		̶		̶
July - December 2020		Collars		5,000		̶		$50.00		$57.09
January - December 2021		Swaps		11,718		$42.29		̶		̶
January - December 2021		Collars		1,000		̶		$30.00		$40.00
January - December 2022		Swaps		3,496		$44.25		̶		̶
Crude-LLS
January - December 2021		Swaps		3,000		$38.83		̶		̶
Natural Gas-HH NYMEX				(MMBtu)		(Per MMBtu)		(Per MMBtu)		(Per MMBtu)
July - December 2020		Swaps		64,261		$2.26		̶		̶
January - December 2021		Swaps		48,737		$2.47		̶		̶
January - December 2021		Collars		5,000		̶		$2.50		$3.10
January - December 2022		Swaps		15,490		$2.42		̶		̶

CONFERENCE CALL AND WEBCAST INFORMATION

Talos will host an earnings conference call, which will be broadcast live over the internet, tomorrow, Thursday, August 6, 2020 at 10:00 AM Eastern Time. Listeners can access the earnings 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 through August 13, 2020 and can be accessed by dialing 1-877-344-7529 and using access code 10146030.

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
[e-mail]

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, including the sharp decline in oil prices beginning in March 2020, the impact of the coronavirus disease 2019 ("COVID-19") and governmental measures related thereto on global demand for oil and natural gas and on the operations of our business, the ability or willingness of the Organization of Petroleum Exporting Countries ("OPEC") and non-OPEC countries, such as Saudi Arabia and Russia, to set and maintain oil production levels and the impact of any such actions, lack of transportation and storage capacity as a result of oversupply, government regulations and actions, including with respect to repairs to the Ram Powell facility, or other factors, 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, the possibility that the anticipated benefits of recent acquisitions are not realized when expected or at all, including as a result of the impact of, or problems arising from, the integration of such acquisitions, 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, 2019 and our Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2020, 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, marketing and storage of oil and gas are subject to disruption due to transportation, processing and storage 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 per share amounts)
	June 30, 2020				December 31, 2019
	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	107,855			$	87,022
Accounts receivable
Trade, net		67,042				107,842
Joint interest, net		52,777				16,552
Other		21,697				6,346
Assets from price risk management activities		72,666				8,393
Prepaid assets		45,689				65,877
Other current assets		1,982				1,952
Total current assets		369,708				293,984
Property and equipment:
Proved properties		4,674,529				4,066,260
Unproved properties, not subject to amortization		274,690				194,532
Other property and equipment		32,262				29,843
Total property and equipment		4,981,481				4,290,635
Accumulated depreciation, depletion and amortization		(2,247,009)				(2,065,023)
Total property and equipment, net		2,734,472				2,225,612
Other long-term assets:
Assets from price risk management activities		1,409				—
Other well equipment inventory		14,458				7,732
Operating lease assets		7,351				7,779
Other assets		47,250				54,375
Total assets	$	3,174,648			$	2,589,482
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable	$	104,151			$	71,357
Accrued liabilities		184,992				154,816
Accrued royalties		12,772				31,729
Current portion of asset retirement obligations		44,977				61,051
Liabilities from price risk management activities		26,615				19,476
Accrued interest payable		10,603				10,249
Current portion of operating lease liabilities		1,695				1,594
Other current liabilities		22,073				20,180
Total current liabilities		407,878				370,452
Long-term liabilities:
Long-term debt, net of discount and deferred financing costs		997,041				732,981
Asset retirement obligations		387,083				308,427
Liabilities from price risk management activities		7,018				511
Operating lease liabilities		19,228				17,239
Other long-term liabilities		61,847				81,595
Total liabilities		1,880,095				1,511,205
Commitments and contingencies (Note 11)
Stockholders' Equity:
Preferred stock, $0.01 par value; 30,000,000 shares authorized and no shares issued or outstanding as of June 30, 2020 and December 31, 2019		—				—
Common stock $0.01 par value; 270,000,000 shares authorized; 68,414,782 and 54,197,004 shares issued and outstanding as of June 30, 2020 and December 31, 2019, respectively		684				542
Additional paid-in capital		1,545,138				1,346,142
Accumulated deficit		(251,269)				(268,407)
Total stockholders' equity		1,294,553				1,078,277
Total liabilities and stockholders' equity	$	3,174,648			$	2,589,482

 

Talos Energy Inc.
Condensed Consolidated Statements of Operations
(In thousands, except per common share amounts)
	Three Months Ended June 30,								Six Months Ended June 30,
	2020				2019				2020				2019
Revenues:
Oil revenue	$	74,471			$	256,908			$	241,095			$	412,587
Natural gas revenue		11,140				14,746				23,038				29,193
NGL revenue		1,964				6,645				6,265				11,711
Other		1,299				8,511				6,240				12,032
Total revenue		88,874				286,810				276,638				465,523
Operating expenses:
Lease operating expense		63,882				54,455				122,123				122,414
Production taxes		166				506				415				1,088
Depreciation, depletion and amortization		88,443				95,806				181,986				160,393
Write-down of oil and natural gas properties		—				12,361				57				12,361
Accretion expense		13,794				9,945				26,211				19,552
General and administrative expense		17,192				18,865				44,661				36,474
Total operating expenses		183,477				191,938				375,453				352,282
Operating income (expense)		(94,603)				94,872				(98,815)				113,241
Interest expense		(26,190)				(24,932)				(52,040)				(50,150)
Price risk management activities income (expense)		(68,682)				29,990				174,535				(79,589)
Other income (expense)		(528)				831				(674)				1,264
Net income (loss) before income taxes		(190,003)				100,761				23,006				(15,234)
Income tax benefit (expense)		49,392				(5,997)				(5,868)				362
Net income (loss)	$	(140,611)			$	94,764			$	17,138			$	(14,872)
Net income (loss) per common share:
Basic	$	(2.14)			$	1.75			$	0.28			$	(0.27)
Diluted	$	(2.14)			$	1.74			$	0.28			$	(0.27)
Weighted average common shares outstanding:
Basic		65,807				54,178				62,023				54,167
Diluted		65,807				54,451				62,318				54,167

 

Talos Energy Inc.
Condensed Consolidated Statements of Cash Flows
(In thousands)
	Six Months Ended June 30,
	2020				2019
Cash flows from operating activities:
Net income (loss)	$	17,138			$	(14,872)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation, depletion, amortization and accretion expense		208,197				179,945
Write-down of oil and natural gas properties and other well inventory		190				12,361
Amortization of deferred financing costs and original issue discount		3,985				2,393
Equity based compensation, net of amounts capitalized		3,974				3,220
Price risk management activities expense (income)		(174,535)				79,589
Net cash received (paid) on settled derivative instruments		122,499				(12,562)
Gain on extinguishment of debt		(1,470)				—
Settlement of asset retirement obligations		(18,496)				(32,206)
Changes in operating assets and liabilities:
Accounts receivable		(5,164)				(32,118)
Other current assets		15,128				12,259
Accounts payable		12,645				23,646
Other current liabilities		16,039				(37,164)
Other non-current assets and liabilities, net		(8,518)				(1,870)
Net cash provided by operating activities		191,612				182,621
Cash flows from investing activities:
Exploration, development and other capital expenditures		(154,628)				(229,601)
Cash paid for acquisitions, net of cash acquired		(296,966)				(32,916)
Proceeds from sale of other property and equipment		—				5,369
Net cash (used in) investing activities		(451,594)				(257,148)
Cash flows from financing activities:
Redemption of Senior Notes and other long-term debt		(1,209)				(10,567)
Proceeds from Bank Credit Facility		300,000				75,000
Repayment of Bank Credit Facility		—				(25,000)
Deferred financing costs		(1,287)				—
Other deferred payments		(7,575)				(9,921)
Payments of finance lease		(8,323)				(6,759)
Employee stock transactions		(791)				(283)
Net cash provided by financing activities		280,815				22,470
Net increase (decrease) in cash, cash equivalents and restricted cash		20,833				(52,057)
Cash, cash equivalents and restricted cash:
Balance, beginning of period		87,022				141,162
Balance, end of period	$	107,855			$	89,105
Supplemental Non-Cash Transactions:
Capital expenditures included in accounts payable and accrued liabilities	$	113,461			$	165,310
Debt exchanged for common stock	$	35,960				—
Supplemental Cash Flow Information:
Interest paid, net of amounts capitalized	$	34,163			$	31,413

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," "EBITDA," "Adjusted EBITDA," "Adjusted EBITDA excluding hedges," "Adjusted EBITDA Margin," "Adjusted EBITDA Margin excluding hedges," "Free Cash Flow," "Cash-Based G&A," "Net Debt," "LTM Adjusted EBITDA" and "Net Debt to LTM 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 EBITDA and Adjusted EBITDA
"EBITDA" and "Adjusted EBITDA" are 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. 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, loss on debt extinguishment, transaction related costs, derivative fair value (gain) loss, net cash receipts (payments) on settled derivatives, non-cash (gain) loss on sale of assets, non-cash write-down of other well equipment inventory and non-cash equity-based compensation expense.  

We also present Adjusted EBITDA excluding hedges and as a percentage of revenue to further analyze our business, which are outlined below:

Adjusted EBITDA Margin. 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.

The following table presents a reconciliation of the GAAP financial measure of net income (loss) to EBITDA, Adjusted EBITDA, 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 ended June 30, 2020			Three Months ended March 31, 2020			Three Months ended December 31, 2019			Three Months ended September 30, 2019
Reconciliation of net income (loss) to Adjusted EBITDA:
Net income (loss)	$	(140,611)		$	157,749		$	304		$	73,297
Interest expense		26,190			25,850			24,574			23,123
Income tax expense (benefit)		(49,392)			55,260			(36,569)			790
Depreciation, depletion and amortization		88,443			93,543			97,413			88,125
Accretion expense		13,794			12,417			7,521			7,316
EBITDA		(61,576)			344,819			93,243			192,651
Write-down of oil and natural gas properties		-			57			(1,557)			1,417
Transaction and non-recurring expenses(2)		3,498			7,758			4,111			146
Derivative fair value (gain) loss(1)		68,682			(243,217)			59,508			(43,760)
Net cash receipts (payments) on settled derivative instruments(1)		86,039			36,460			(1,618)			5,360
Gain on extinguishment of debt		(1,470)			-			(1,470)			-
Non-cash write-down of other well equipment inventory		-			133			165			-
Non-cash equity-based compensation expense		2,347			1,627			1,800			1,944
Adjusted EBITDA		97,520			147,637			154,182			157,758
Net cash receipts (payments) on settled derivative instruments(1)		(86,039)			(36,460)			1,618			(5,360)
Adjusted EBITDA excluding hedges		11,481			111,177			155,800			152,398
Production and Revenue:
Boe(2)		4,775			5,287			4,966			4,843
Revenue - Operations		87,575			182,823			233,240			227,828
Adjusted EBITDA margin and Adjusted EBITDA excl hedges margin:
Adjusted EBITDA divided by Revenue - Operations (%)		111%			81%			66%			69%
Adjusted EBITDA per Boe(2)	$	20.41		$	27.92		$	31.05		$	32.57
Adjusted EBITDA excl hedges divided by Revenue - Operations (%)		13%			61%			67%			67%
Adjusted EBITDA excl hedges per Boe(2)	$	2.40		$	21.03		$	31.37		$	31.47

(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 EBITDA to Free Cash Flow
We believe the presentation of Free Cash Flow is important to provide investors with additional important information to evaluate our business. These measures are widely used by investors in the valuation, comparison, rating and investment recommendations of companies. Please see "Reconciliation of Net Income (Loss) to EBITDA and Adjusted EBITDA" above.

($ thousands, except per share amounts)		Three Months Ended June 30, 2020
Reconciliation of Adjusted EBITDA to Free Cash Flow
Adjusted EBITDA		$	97,519
Less: Capital Expenditures and Plugging & Abandonment			(129,050)
Less: Interest Expense			(26,190)
Free Cash Flow		$	(57,721)

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

($ thousands, except per share amounts)		Three Months Ended June 30, 2020
Reconciliation of Net Income to Adjusted Net Income:
Net Income		$	(140,611)
Transaction related costs			3,498
Derivative fair value (gain) loss(1)			68,682
Net cash receipts (payments) on settled derivative instruments(1)			86,039
Non-cash income tax expense			(49,392)
Non-cash equity-based compensation expense			2,347
Adjusted Net Income		$	(29,437)
Weighted average common shares outstanding at March 31, 2020:
Basic			65,807
Diluted			65,807
Loss per common share:
Basic		$	(2.14)
Diluted		$	(2.14)
Adjusted Loss per common share:
Basic		$	(0.45)
Diluted		$	(0.45)

(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 Net Income on a cash basis during the period the derivatives settled.

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

We believe the presentation of Net Debt, LTM Adjusted EBITDA, Credit Facility LTM Adjusted EBITDA, Net Debt to LTM Adjusted EBITDA and Net Debt to Credit Facility 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 of the Company plus the Finance Lease balance minus Cash.

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

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

Reconciliation of Net Debt ($ thousands) at December 31, 2019:
11.00% Second-Priority Senior Secured Notes – due April 2022		$	351,659
7.50% Senior Notes – due May 2022			6,060
Bank Credit Facility – matures May 2022			650,000
Finance lease			71,212
Total Debt		$	1,078,931
Less: Cash and cash equivalent			(107,855)
Net Debt		$	971,076
Calculation of LTM EBITDA:
Adjusted EBITDA for three months period ended September 30, 2019		$	157,758
Adjusted EBITDA for three months period ended December 31, 2019			155,784
Adjusted EBITDA for three months period ended March 31, 2020			147,619
Adjusted EBITDA for three months period ended June 30, 2020			97,519
LTM Adjusted EBITDA		$	558,680
ILX/Castex Assets Adjusted EBITDA for eight months prior to closing			135,345
Credit Facility LTM Adjusted EBITDA		$	694,025
Reconciliation of Net Debt to LTM Adjusted EBITDA:
Net Debt / LTM Adjusted EBITDA			1.7x
Net Debt / Credit Facility LTM Adjusted EBITDA			1.4x

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 Credit Facility LTM Adjusted EBITDA ratio, as determined in accordance with the Company's credit agreement, equal to or lower than 3.0x. For purposes of covenant compliance, Credit Facility LTM Adjusted EBITDA, with certain adjustments, is calculated as the sum of quarterly Adjusted EBITDA for the 12-month period ended on that quarter, inclusive of revenue less direct operating expenditures of the Acquired Assets for periods prior to closing of the Transaction.

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