Gulfport Energy Corporation — Q2 2023 Form 10-Q Summary
Business context and reporting period
Gulfport is a natural-gas-weighted exploration and production company operating primarily in eastern Ohio’s Utica and Marcellus plays and central Oklahoma’s SCOOP. This unaudited Form 10-Q covers the three and six months ended June 30, 2023, compared with the corresponding 2022 periods.
Financial and operating metrics
| Metric | Q2 2023 | Q2 2022 | Six months 2023 | Six months 2022 |
|---|---|---|---|---|
| Total revenues | $304.7 million | $465.3 million | $1,035.9 million | $157.5 million |
| Commodity sales, excluding derivatives | $207.9 million | $638.2 million | $561.1 million | $1,118.9 million |
| Net gain (loss) on derivatives | $96.8 million | $(172.9) million | $474.8 million | $(961.4) million |
| Net income | $93.7 million | $256.6 million | $616.7 million | $(235.4) million |
| Net income attributable to common stockholders | $78.4 million | $215.6 million | $521.5 million | $(238.2) million |
| Diluted EPS | $4.18 | $10.34 | $27.60 | $(11.36) |
| Cash flow from operations | $107.4 million | Not separately provided | $411.4 million | $383.2 million |
| Capital expenditures | Not separately provided | Not separately provided | $283.4 million cash; $276.2 million incurred | $181.8 million cash |
Q2 operating income was $102.6 million, representing an operating margin of approximately 33.7%; net income margin was approximately 30.8%. Six-month operating income was $625.2 million, but results were heavily influenced by derivative gains, including $411.9 million of fair-value gains.
Production averaged 1,039.3 MMcfe per day in Q2, up 8% year over year, and 1,048.3 MMcfe per day for the first six months, up 7%. Q2 commodity sales declined 67% because lower prices more than offset higher production. Realized Q2 prices including settled derivatives were $2.76 per Mcfe, $71.45 per barrel for oil and condensate, and $26.27 per barrel for NGLs.
At June 30, 2023, cash and cash equivalents were $5.3 million, total assets were $2.56 billion, and stockholders’ equity was $1.38 billion. Total principal funded debt was $649.0 million, consisting of $550.0 million of 8.0% senior notes due 2026 and $99.0 million drawn under the Credit Facility. The Company also had $74.4 million of outstanding letters of credit. The Credit Facility borrowing base was increased to $1.1 billion, elected commitments to $900 million, and maturity was extended to May 2027, subject to specified conditions.
Material changes versus the prior comparable period
- Commodity sales fell sharply as average Henry Hub gas prices declined to $2.10 per Mcf in Q2 2023 from $7.17, while WTI declined to $73.78 per barrel from $108.41 and Mont Belvieu NGL prices declined to $25.99 per barrel from $51.49.
- Derivative results improved materially, producing a $96.8 million Q2 gain versus a $172.9 million loss in Q2 2022 and a $474.8 million six-month gain versus a $961.4 million loss.
- Production increased, primarily from the 2022 and 2023 development programs. Transportation, gathering, processing and compression expense declined 10% per unit in Q2 and 6% for the six-month period.
- Depreciation, depletion and amortization increased 28% in both the quarter and six-month period due principally to additional drilling and development.
- Credit Facility interest rates increased materially, with the weighted-average rate rising to 8.13% in Q2 and 7.85% for the six months, versus 4.01% and 3.59%, respectively, in the prior-year periods.
- The Company recorded $2.9 million in Q2 and $4.8 million year to date of personnel-related restructuring costs associated with leadership changes, including $0.8 million and $1.3 million of non-cash accelerated equity vesting charges.
- Gulfport repurchased approximately 900,599 shares for $74.2 million during the first six months. Approximately $75 million remained available under the $400 million program at June 30, 2023.
Guidance, outlook, commentary and risks
Management estimates 2023 drilling and completion capital expenditures of $375 million to $400 million, maintenance leasehold and land investment of approximately $50 million to $75 million, and discretionary acreage acquisitions of approximately $40 million. The program is expected to generate 2023 production of approximately 1,035 to 1,055 MMcfe per day.
Management believes operating cash flow, Credit Facility availability and cash on hand will fund operations, capital expenditures, interest and planned repurchases during the next 12 months. Liquidity remains sensitive to commodity prices, production performance, capital spending, interest rates and access to debt or equity markets.
The Company had a net derivative asset of $74.1 million at June 30, 2023, compared with a net derivative liability of $347.9 million at December 31, 2022. A 10% increase in underlying commodity prices would have increased derivative liabilities by approximately $119.5 million, while a 10% decrease would have reduced them by approximately $115.6 million. Hedging limits upside participation and can create losses if production is below forecast or commodity prices rise.
Material contractual commitments include approximately $1.48 billion of future firm transportation and gathering commitments, $70.8 million of remaining inventory and other material commitments through 2024, $74.4 million of letters of credit and $37.8 million of surety bonds. The Company also faces litigation and environmental risks, including Ohio restrictive-covenant matters and claims concerning production from formations below the Marcellus and Utica. Management does not currently believe pending matters are likely to have a material adverse effect, but final outcomes could exceed accrued amounts.
The Company recorded no income tax expense because it maintains a full valuation allowance against deferred tax assets. Future taxable income could result in a valuation allowance reversal, but the timing and amount are uncertain.
Important facts for investors to verify
- Reconcile reported revenue and earnings to underlying commodity sales, realized prices and derivative gains, particularly the significant six-month derivative benefit.
- Assess liquidity after planned capital expenditures, preferred dividends, share repurchases and the large future transportation and gathering commitments.
- Monitor the $550 million senior notes maturity in May 2026 and the Credit Facility’s maturity provisions tied to the senior notes.
- Evaluate exposure to lower natural gas prices, higher floating-rate interest expense and potential hedge losses or reduced upside.
- Review production execution against the 2023 guidance range of 1,035–1,055 MMcfe per day and capital spending of up to approximately $515 million before discretionary acreage acquisitions.
- Track remaining preferred stock, which had a $46.5 million carrying amount and could convert into approximately 3.3 million common shares, as well as ongoing share repurchases and dilution.
- Follow the resolution of Ohio litigation, bankruptcy-related claim distributions and other contingent obligations.