Antero Resources Corporation — Q1 2024 Form 10-Q
Business context and reporting period
Antero Resources is an Appalachian Basin oil and gas producer, with operations in West Virginia and Ohio. This unaudited quarterly report covers the three months ended March 31, 2024; comparisons are with Q1 2023 unless stated otherwise. The company reported approximately 517,000 net acres and production of 312 Bcfe, up 6% year over year.
Financial and operating performance
| Metric | Q1 2024 | Q1 2023 |
|---|---|---|
| Total revenue | $1.122 billion | $1.408 billion |
| Operating income | $65 million | $331 million |
| Net income attributable to Antero | $36 million | $213 million |
| Diluted earnings per share | $0.12 | $0.69 |
| Cash provided by operating activities | $262 million | $344 million |
| Cash used in investing activities | $227 million | $351 million |
- Revenue fell about 20%, operating income about 80%, and attributable net income about 83%. Operating margin was approximately 5.8%, versus 23.5% in Q1 2023.
- Natural gas sales decreased 29% to $474 million, primarily reflecting lower prices; average realized natural gas price before derivative settlements fell 32% to $2.35/Mcf. NGL sales rose 5% to $518 million and oil sales rose 25% to $65 million, supported by higher volumes.
- Average daily combined production increased 5% to 3,426 MMcfe/d. Natural gas production rose 4%, NGLs 8% combined, and oil 25%.
- Net cash used in investing fell to $227 million, primarily due to reduced drilling, completion and leasing activity. Operating cash flow less investing cash flow was approximately $35 million.
- At March 31, total assets were $13.55 billion and total equity was $7.27 billion. Current assets were $403 million versus current liabilities of $1.38 billion; reported cash and cash equivalents were zero.
- Long-term debt carrying value was $1.510 billion ($1.519 billion principal). Credit Facility borrowings were $415 million, with $752 million of available borrowing capacity; the company reported compliance with financial covenants. Operating and finance lease liabilities totaled approximately $2.935 billion.
Material changes and unusual items
- Commodity derivative fair-value gains were $9 million, compared with $126 million in Q1 2023. The prior-year comparison included a $202 million cash payment for early settlement of a natural gas swaption, affecting operating cash flow presentation.
- Q1 2023 included a $24 million payment to terminate firm transportation capacity; no such contract-termination expense was reported in Q1 2024.
- Gathering, compression, processing and transportation expense increased 4% to $672 million, while production and ad valorem taxes increased 18% to $58 million. Higher throughput and expiration of a midstream fee-rebate program contributed to higher Antero Midstream segment revenue.
- All remaining $26 million principal of the 4.25% convertible notes converted during Q1 2024 into approximately 6 million common shares. Shares outstanding at March 31 were 310.2 million, up from 303.5 million at year-end.
Outlook, risks and contingencies
- Management’s 2024 net capital budget is $725 million–$800 million: $650 million–$700 million for drilling and completion and $75 million–$100 million for leasehold expenditures. The company plans to complete 45–50 net horizontal wells. Q1 capital expenditures were reported as $219 million.
- Based on March 31 strip prices, management believes operating cash flow and available Credit Facility borrowings will cover operating needs, debt service, capital expenditures and commitments for at least the next 12 months. Results remain exposed to commodity prices, production, costs, market access and financing conditions.
- Management reported that natural gas benchmark prices declined significantly year over year, while NGL and oil benchmarks were broadly consistent. It expects commodity-price and derivative fair-value volatility to continue. Only 1% of production was hedged through fixed-price swaps in Q1 2024; hedge coverage had declined as liquidity and leverage improved.
- Contractual obligations include approximately $9.9 billion of firm transportation commitments and $13.7 billion of total listed future minimum contractual payments, including leases. These are gross scheduled amounts and may not equal the company’s eventual share of costs.
- Environmental notices from the EPA and West Virginia regulators concern alleged air-permitting violations; operations have not been suspended and management does not expect a material adverse effect. Royalty-cost litigation remains uncertain: courts issued rulings against certain post-production cost deductions in two cases, with alleged damages in those cases described as not material. The company cannot estimate potential impacts in other cases.
Important facts for investors to verify
- How much of the sharp earnings decline reflects weaker natural gas prices versus derivative accounting and other nonrecurring comparative items.
- Whether operating cash flow and the $752 million of available Credit Facility capacity remain sufficient under lower commodity prices and planned capital spending.
- Execution of the $725 million–$800 million capital budget, planned well completions, and resulting production and cash generation.
- Exposure from firm transportation and lease commitments, including payment obligations and capacity utilization.
- Developments in EPA and state environmental matters and royalty litigation, and any resulting costs or changes to deductions.