Talos Energy Inc. — 2024 Q1 Form 10-Q Summary
Business context and reporting period
Talos Energy is an independent exploration and production company operating primarily in the U.S. Gulf of Mexico and offshore Mexico. The filing covers the three months ended March 31, 2024. Talos completed the QuarterNorth Acquisition on March 4, 2024 and sold its entire carbon capture and sequestration business on March 18, 2024, leaving the company with one operating segment focused on upstream oil and gas.
Financial performance and liquidity
| Metric | Q1 2024 | Q1 2023 | Change |
|---|---|---|---|
| Total revenue | $429.9 million | $322.6 million | 33% |
| Operating income | $67.8 million | $7.9 million | Higher |
| Net income (loss) | $(112.4) million | $89.9 million | Decline |
| Basic EPS | $(0.71) | $0.85 | Decline |
| Adjusted EBITDA | $257.7 million | $203.1 million | 27% |
| Cash flow from operations | $96.4 million | $62.9 million | 53% |
| Capital expenditures | $146.1 million | $104.0 million | 40% |
Revenue growth was driven primarily by higher production volumes and oil prices. Production increased to 79.6 MBoepd from 63.6 MBoepd, including contributions from QuarterNorth, EnVen and new Venice and Lime Rock wells. Average realized price per Boe increased to $59.32 from $56.37, or to $58.84 including realized derivatives.
Operating margin was approximately 15.8%, compared with 2.4% in the prior-year quarter. Net margin was approximately negative 26.2%, compared with positive 27.9% in Q1 2023. The net loss reflected an $87.1 million loss from price risk management activities, including an $83.6 million unrealized derivative loss, a $60.3 million loss on debt extinguishment, and $28.1 million of QuarterNorth transaction and severance costs. A $86.9 million gain on the CCS divestiture partially offset these items.
Cash and cash equivalents were $21.0 million at March 31, 2024, while total cash, cash equivalents and restricted cash were $124.4 million. Management reported available liquidity of $650.2 million, consisting of cash and available Bank Credit Facility capacity.
Total debt before discounts, premiums and deferred financing costs was $1.575 billion, compared with $1.066 billion at December 31, 2023. Debt consisted primarily of $625.0 million of 9.000% notes due 2029, $625.0 million of 9.375% notes due 2031 and $325.0 million outstanding under the Bank Credit Facility. The company redeemed $638.5 million of 12.000% notes and $227.5 million of 11.750% notes. Talos stated that it was in compliance with all debt covenants.
Material changes versus the prior comparable period
- QuarterNorth was acquired for $1.247 billion in cash and 24.3 million Talos shares valued at $322.6 million. The acquisition contributed $43.9 million of revenue and $6.7 million of net income from March 4 through March 31.
- The acquisition was funded through new senior notes, Bank Credit Facility borrowings and a 34.5 million-share public offering that generated $387.7 million of proceeds.
- Talos sold Talos Low Carbon Solutions, including its CCS investments, for approximately $142.0 million and recorded an $86.9 million gain.
- Production increased 25% to 79.6 MBoepd. Oil production rose to 56.8 MBblpd from 45.6 MBblpd.
- Lease operating expense increased 66% to $135.2 million, and cost per Boe increased to $18.65 from $14.22, partly due to major well workovers and acquired assets.
- Depreciation, depletion and amortization increased 46% to $215.7 million, reflecting higher production and a higher depletion rate.
- Operating cash flow increased, but investing cash use rose to $937.6 million, primarily because of the QuarterNorth acquisition. Financing cash flow was $829.6 million.
Guidance, outlook, commentary and risks
Management expects operating cash flow and available Bank Credit Facility capacity to fund the remaining 2024 upstream capital program of $570 million to $600 million, plus $90 million to $100 million of plugging, abandonment and decommissioning obligations. No formal revenue or earnings guidance was provided.
The Phoenix Field is expected to experience approximately 55 days of shut-in during the second quarter of 2024 while the Helix Producer I undergoes scheduled dry-dock inspection. The company also reported approximately 2.0 MBoepd of deferred production in the first quarter from third-party infrastructure downtime.
Commodity prices remain a major risk. Talos reported first-quarter NYMEX WTI prices ranging from $70.62 to $84.39 per barrel and Henry Hub natural gas prices ranging from $1.25 to $13.20 per MMBtu. The filing cites an EIA expectation for average 2024 WTI of $83.78 per barrel and natural gas of $2.15 per MMBtu, but these are external market estimates rather than Talos guidance.
At March 31, 2024, derivatives produced a net liability of $53.7 million and covered future production through December 2025. A hypothetical 10% increase in oil and gas prices would have reduced derivative fair value by approximately $121.4 million, while a 10% decrease would have increased fair value by approximately $122.4 million.
Talos faces increased potential financial assurance requirements under BOEM’s April 2024 offshore bonding rule. The company had $1.5 billion of performance bonds and $10.8 million of letters of credit outstanding. Its asset retirement obligations totaled $1.109 billion, excluding certain other decommissioning liabilities.
U.S. Specialty Insurance Company sued in connection with approximately $80.0 million of QuarterNorth surety bonds and sought collateral; some buyers temporarily withheld production payments. Talos expected to replace most or all of the bonds during the second quarter of 2024. The company also paid a $14.4 million judgment related to litigation inherited from EnVen.
Other key risks include oil, gas and NGL price volatility, offshore operational and weather risks, third-party infrastructure downtime, inflation and interest rates, reserve and ceiling-test sensitivity, regulatory and permitting changes, environmental liabilities, cybersecurity, and integration risk from the QuarterNorth acquisition. A 10% reduction in the commodity prices used in the March 31 ceiling test would have resulted in an estimated $446.5 million impairment, with other assumptions unchanged.
Most important facts for investors to verify
- Whether QuarterNorth production and cost synergies are achieved and fully integrated without further material transaction or severance costs.
- The effect of the Phoenix Field dry-dock and other third-party outages on second-quarter production and cash flow.
- Future borrowing-base redeterminations, available liquidity and compliance with debt covenants following the acquisition-related increase in leverage.
- The amount and timing of supplemental financial assurance required under the BOEM bonding rule.
- The resolution of the USSI surety-bond dispute and any production-payment withholding.
- Commodity-price exposure, derivative settlements and the potential earnings impact of mark-to-market losses or gains.
- The final purchase-price allocation for QuarterNorth, which remained preliminary and could materially change through December 31, 2024.
- Actual 2024 upstream capital spending and plugging, abandonment and decommissioning costs versus management’s stated ranges.