EQT Corporation — 2022 Form 10-K Summary
Reporting period: Fiscal year ended December 31, 2022. This annual filing reports full-year results, not standalone fourth-quarter results. EQT is a natural gas producer focused on the Appalachian Basin, with one reportable segment and 25.0 Tcfe of proved reserves at year-end.
Key financial and operating metrics
| Metric | 2022 | 2021 |
|---|---|---|
| Total operating revenues | $7.498 billion | $3.065 billion |
| Net income (loss) attributable to EQT | $1.771 billion; diluted EPS $4.38 | $(1.143) billion; diluted EPS $(3.54) |
| Operating income (loss) | $2.718 billion | $(1.361) billion |
| Net cash provided by operating activities | $3.466 billion | $1.662 billion |
| Cash capital expenditures | $1.400 billion | $1.055 billion |
| Sales volume | 1,940 Bcfe; 5.315 Bcfe/day | 1,858 Bcfe; 5.090 Bcfe/day |
| Average realized price, including cash-settled derivatives | $3.17/Mcfe | $2.50/Mcfe |
| Debt outstanding, principal value | $5.727 billion | $5.644 billion |
| Cash and cash equivalents | $1.459 billion | $114 million |
Operating margin was approximately 36% and net margin approximately 24% in 2022, calculated using reported operating income and net income attributable to EQT divided by total operating revenues. Cash flow from operations less cash capital expenditures was approximately $2.065 billion; this is a simple calculation, not a company-reported non-GAAP free-cash-flow measure.
Performance and changes versus 2021
- Operating revenues rose 145%, while sales of natural gas, NGLs and oil increased 78% to $12.114 billion. The reported total includes a $4.643 billion derivative loss; settled derivative cash payments were $5.928 billion.
- Net income returned to profit, primarily reflecting higher commodity sales revenues, partly offset by derivative losses, income tax expense, higher transportation and processing costs, and a $214 million contract-asset impairment.
- Sales volume increased 4.4%, primarily reflecting acquired production, partly offset by natural decline, fewer wells turned in line, and supply-chain constraints. Marcellus volume grew, while Ohio Utica volume declined.
- Cash from operations more than doubled. Cash capital spending increased to $1.400 billion, and investing cash use fell to $1.422 billion from $2.073 billion, in part reflecting lower acquisition spending and proceeds from selling the remaining Equitrans Midstream investment.
- At year-end, total assets were $22.670 billion and total liabilities $11.457 billion. Current assets of $4.014 billion exceeded current liabilities of $3.732 billion. EQT reported $5.727 billion of debt principal and $1.459 billion of cash. Its $2.5 billion revolving credit facility had no year-end borrowings; letters of credit were approximately $25 million.
Capital allocation, outlook and management commentary
- For 2023, EQT expected capital expenditures of $1.7–$1.9 billion and sales volume of 1,900–2,000 Bcfe, excluding acquisition volumes. Spending was expected to focus mainly on reserve development.
- Management’s stated goal was to retire at least $4.0 billion of debt from January 1, 2022 through December 31, 2023, subject to the acquisition closing and commodity-market performance. EQT reported repaying or repurchasing $826 million of senior-note principal in 2022 and separately repurchased $85 million principal of convertible notes.
- EQT repurchased $393 million of common stock in 2022 and paid $204 million in dividends. The quarterly base dividend was increased 20% to $0.15 per share, or $0.60 annualized. A share-repurchase authorization of up to $2.0 billion remained in place through December 31, 2023.
- The pending Tug Hill and XcL Midstream acquisition was agreed for approximately $2.6 billion in cash and 55 million EQT shares, subject to customary adjustments and regulatory approvals. The acquired assets were reported to produce approximately 800 MMcfe/day. The agreement’s outside date was extended to December 29, 2023.
- Management cited high commodity-price volatility, inflation, third-party supply-chain constraints and potential cost and schedule impacts. EQT said its hedging strategy was intended to reduce price volatility, while noting that hedges can limit gains when market prices rise.
Risks, contingencies and unusual items
- Commodity and hedge exposure: Natural gas prices, regional basis differentials and NGL prices materially affect revenue, liquidity and reserve economics. The $4.643 billion reported derivative loss chiefly reflected increases in NYMEX forward prices; it is distinct from cash settlements and should not be interpreted alone as the period’s cash hedge impact.
- Infrastructure and concentration: Operations are concentrated in the Appalachian Basin, and a substantial majority of midstream and water services come from Equitrans Midstream’s EQM subsidiary. Long-term pipeline, gathering and processing commitments can require payment even when capacity is underused. Pipeline delays, including Mountain Valley Pipeline uncertainty, may affect market access and contract economics.
- Acquisition and financing conditions: The FTC issued a second request for information on the Tug Hill and XcL transaction. The $150 million advanced to the upstream seller became an unsecured note; the filing describes risks if the acquisition does not close. The 2022-issued acquisition-funding notes also included a special mandatory redemption provision if specified transaction conditions were not met.
- Environmental and legal matters: Risks include methane and other emissions rules, hydraulic-fracturing and water regulation, permitting delays, and possible climate-related costs. EQT disclosed an ongoing produced-water release remediation in Pennsylvania and anticipated penalties exceeding $300,000, which it did not expect to materially affect its financial position, results or liquidity. Securities litigation related to the 2017 Rice merger remained pending; EQT could not estimate reasonably possible losses.
- Notable accounting and other items: EQT recorded a $214 million impairment of its Mountain Valley Pipeline-related contract asset and exercised a $196 million cash-payment option, reducing the asset’s carrying value to zero. Lease impairment and expiration expense was $177 million, down from $312 million in 2021. Debt-extinguishment loss was $140 million. Income tax expense was $554 million, including significant deferred tax expense. These items affect comparability and should be considered alongside operating cash flows.
- Proved reserves increased 0.2% to 25.003 Tcfe. Proved undeveloped reserves fell 3.3%, including negative revisions where third-party impacts pushed development beyond the five-year booking window. The standardized measure of discounted future net cash flows was $40.065 billion, but it is not an estimate of market value and uses SEC-prescribed pricing assumptions.
The independent auditor issued an unqualified opinion on the financial statements and internal controls. No material weakness in internal control over financial reporting was reported.
Important facts for investors to verify
- Reconcile GAAP operating revenue and derivative mark-to-market losses with cash settlements and the company’s adjusted operating-revenue measure.
- Track actual 2023 production, capital spending, operating costs and free cash flow against management’s outlook, including continuing supply-chain and inflation effects.
- Verify the status, consideration, regulatory conditions and financing implications of the Tug Hill and XcL Midstream acquisition, including potential share dilution and note-redemption terms.
- Monitor debt reduction against the stated $4.0 billion goal, liquidity and collateral needs, credit ratings, and the timing of debt maturities.
- Assess the durability of proved-reserve additions and revisions, lease expirations, and sensitivity of reserve values to commodity prices and development timing.
- Follow Mountain Valley Pipeline timing, EQM service commitments, environmental remediation, emissions regulation and the unresolved litigation disclosures.