Business Context and Reporting Period
Comstock Resources, Inc. filed this Form 10-K for the fiscal year ended December 31, 2023; it reports full-year results, not standalone fourth-quarter results. The company is an independent natural gas producer focused primarily on the Haynesville and Bossier shales in North Louisiana and East Texas. About 99% of proved reserves were in these plays.
Key Financial and Operating Metrics
| Metric | 2023 | 2022 |
|---|---|---|
| Total revenue | $1.565 billion | $3.628 billion |
| Natural gas and oil sales | $1.265 billion | $3.125 billion |
| Operating income | $226.6 million | $2.281 billion |
| Net income available to common stockholders | $211.9 million; $0.76 diluted EPS | $1.125 billion; $4.11 diluted EPS |
| Cash from operating activities | $1.017 billion | $1.698 billion |
| Cash capital expenditures | $1.459 billion | $1.102 billion |
| Cash and cash equivalents at year-end | $16.7 million | $54.7 million |
| Debt principal at year-end | $2.669 billion | $2.189 billion |
Natural gas production rose 5% to 524.5 Bcf (about 1.4 Bcf/d), while the average realized gas price fell to $2.40/Mcf from $6.23/Mcf. Including derivative cash settlements, realized gas price was $2.55/Mcf versus $4.50/Mcf. Gas services revenue was $300.5 million; the activity began in 2022.
Operating margin, calculated as operating income divided by total revenue, was about 14.5% in 2023 versus 62.9% in 2022. Net margin on the same revenue basis was about 13.5% versus 31.0%. Operating cash flow less cash capital expenditures was approximately negative $442 million in 2023; this is a simple calculation, not a company-reported non-GAAP measure.
Net derivative gains were $187.6 million in 2023, compared with net losses of $662.5 million in 2022. Interest expense was $169.0 million. The company paid $0.50 per common share in dividends during 2023.
Year-end proved reserves were 4.94 Tcfe, down from 6.70 Tcfe in 2022. Reserve PV10 was $2.50 billion; the after-tax standardized measure was $2.37 billion. The company’s alternative-price sensitivity case showed 6.64 Tcfe and $5.17 billion PV10, based on higher assumed prices and unchanged other assumptions.
Material Changes Versus the Prior Comparable Period
- Total revenue fell 57%, and net income available to common stockholders fell about 81%, primarily because of lower natural gas prices.
- Operating cash flow declined 40% to $1.017 billion, while cash capital expenditures increased to $1.459 billion.
- Debt principal increased to $2.669 billion, including $480 million drawn on the bank credit facility at year-end; the company had no facility borrowing at the end of 2022.
- Proved reserves declined about 26%. At the SEC reserve gas price of $2.39/Mcf, 164 previously booked undeveloped locations no longer generated an economic return. Proved undeveloped gas reserves fell from 4.17 Tcf to 2.21 Tcf.
- Derivative results shifted from a $662.5 million loss in 2022 to a $187.6 million gain in 2023. The 2022 comparison also included a $46.8 million loss on early debt retirement; there was no such loss in 2023.
Guidance, Outlook, Risks, and Unusual Items
For 2024, management expects to spend approximately $750–$850 million on exploration and development, primarily in Haynesville/Bossier, and an additional $125–$150 million through the Western Haynesville midstream partnership. The operating plan calls for five operated rigs, drilling 46 operated horizontal wells (35.9 net) and turning 44 operated wells (38.2 net) to sales. Management described the plan as conservative given low gas prices, with a stated priority of protecting the balance sheet. It expects to fund activity with operating cash flow and, as needed, bank-facility borrowings.
At year-end, the company reported approximately $1.0 billion of liquidity, comprising about $1.0 billion of unused facility capacity and $16.7 million of cash. The $1.5 billion facility matures in November 2027 and has a $2.0 billion borrowing base. The company was in compliance with its leverage and adjusted-current-ratio covenants. Its debt includes fixed-rate senior notes due in 2029 and 2030 and variable-rate facility borrowings.
Key risks include volatile natural gas prices; reserve and production-estimate uncertainty; the capital required to sustain drilling and replace production; debt service and variable interest rates; transportation and gathering commitments; operational, environmental, regulatory, climate-related and cybersecurity risks; and potential limits on access to capital. Transportation and gathering commitments extend to 2031. Management reported no legal proceeding it believes would have a material adverse effect and no material amounts accrued for litigation contingencies.
The Western Haynesville midstream partnership was formed in 2023. Quantum committed up to $300 million for future system expansion; its distribution terms include a 12% dividend on invested capital and preferential distributions until agreed return hurdles are met. The company consolidates the partnership. Management reported successful results from its first seven Western Haynesville exploratory wells turned to sales in 2022 and 2023 and plans ten additional wells there in 2024.
Reserve values are particularly sensitive to commodity-price assumptions: SEC reserve pricing used $2.39/Mcf gas in 2023 versus $6.03/Mcf in 2022. The reserve estimates were audited by Netherland, Sewell & Associates, whose aggregate estimates differed from management’s by no more than 2%. Ernst & Young issued unqualified opinions on the financial statements and internal control over financial reporting.
Most Important Facts for Investors to Verify
- Whether realized gas prices, hedging settlements and production volumes support the 2024 cash-flow plan and planned capital spending.
- How reserve volumes and PV10 respond to actual prices, drilling results and revisions, especially after the significant 2023 proved undeveloped reserve reduction.
- Debt, facility availability, borrowing-base redeterminations, variable-rate interest exposure and compliance with covenants as spending and cash flow evolve.
- Whether the 2024 well plan and midstream buildout are delivered within budget, and the partnership’s preferential distribution economics and consolidation effects.
- The level and economics of firm transportation obligations relative to production and market access, including potential costs if contracted volumes are not delivered.