Range Resources (RRC) Q3 2026 earnings review
Range Resources hits its production target early and cuts debt
Range Resources, an Appalachian natural gas and liquids producer, pumped record liquids volumes and agreed to merge with EQT Corporation. Total daily production climbed 12% from a year ago as new processing plants started up, hitting the company's year-end target a quarter early. Lower capital spending lifted free cash flow to $138 million by our math, cutting net debt by $87 million.
| Oil, gas and NGL sales (before hedges) | $737.9M +20.7% from a year ago |
|---|---|
| Profit per share, excluding one-offs | $0.81 +42% from a year ago |
| Average daily production | 2.50 Bcfe/d +12.2% from a year ago |
| 2026 well connection plan | Unchanged 68 wells (13 left for Q4) |
⚖️ Verdict: 🟢 Bullish
The story got better because the new processing plants started up smoothly and lifted output to 2.50 billion cubic feet equivalent per day, removing the main execution risk for the second-half ramp. One caution: unhedged natural gas prices fell 7% from a year ago on wider regional discounts, and export premiums for natural gas liquids shrank for a second straight quarter.
The question now is how the combined EQT business will allocate capital once the remaining 13 planned wells come online in the fourth quarter. Theforthcoming Form S-4 merger proxy and fourth-quarter production results will settle the combined plan.
🐂 Bull Case
New Processing Plants Lifted Production Early
Range Resources produces natural gas and natural gas liquids (NGLs, such as ethane and propane) in the Appalachian Basin. Management's multi-year plan relied on new midstream processing plants opening in mid-2026 to handle extra volume from its backlog of drilled, uncompleted wells.
Chief executive Dennis Degner said "key infrastructure was commissioned in Range’s liquids-rich area" during the third quarter. The drillers connected 17 wells to sales lines, drawing down their drilled backlog by about 62,000 lateral feet by our math and pushing total output up 12.2% from a year ago.
- Total daily production: 2.50 billion cubic feet equivalent (Bcfe) per day, beating the 2.40 Bcfe third-quarter target
- Liquids production: a company record of 133,173 barrels per day, up 15.2% from a year ago by our math
- Oil, gas and NGL sales before hedges: $737.9 million, up 20.7% from a year ago
This surge matters because the producer reached its planned 2.50 Bcfe per day year-end exit rate three months ahead of schedule. The smooth plant startup removes the main operational risk that stood in the way of its second-half volume targets.
What to watch: fourth-quarter daily production when annual results arrive. Holding 2.50 Bcfe per day with only 13 remaining well connections planned for the fourth quarter will prove the new wells can offset natural field declines.
Free Cash Flow Cut Net Debt By $87 Million
In the second quarter, peak drilling activity and working-capital timing shrank free cash flow to $13.0 million and pushed net debt up by $47.0 million. Management said capital spending would step down in the second half as spot drilling equipment left the field.
Third-quarter capital spending fell to $170.0 million from $222.0 million in the second quarter, while operating cash flow rose 24.3% from a year ago to $307.6 million. By our math, that left $137.6 million in free cash flow, which the Texas-based group used to pay down its bank credit line and cut net debt to $794.0 million.
Lower debt and January's redemption of 8.25% senior notes cut interest expense by 1.5 percentage points of revenue from a year ago, to $0.06 per thousand cubic feet equivalent (mcfe). Because transportation and processing costs rose 1.3 percentage points of revenue on higher NGL prices, that interest savings kept total cash unit costs unchanged at $1.91 per mcfe.
What to watch: fourth-quarter credit facility borrowings in the annual filing. With share buybacks paused and about $149 million of capital spending left in the budget by our math, another debt drop will confirm cash generation stays high.
🐻 Bear Case
Unhedged Gas Prices Fell Below Last Year
Degner said Range will exit the year "in the strongest position in Range’s history." Yet natural gas still accounts for 68% of total production volume, and local Appalachian gas prices weakened during the quarter.
The benchmark NYMEX natural gas price averaged $2.95 per thousand cubic feet (mcf), and the producer's regional discount widened to $0.55 per mcf (including basis hedges) from $0.47 in the second quarter. That pushed its realized gas price before NYMEX hedges down 7.0% from a year ago to $2.38 per mcf, so gas sales before hedges rose only 3.0% despite an 10.8% jump in gas volume.
Range's financial hedges added $0.34 per mcf in cash settlements, lifting its post-hedge gas price to $2.74 per mcf (still down 7.4% from a year ago). Adding 11% more gas into a weak local market shows that volume growth alone cannot lift gas revenue when regional pipelines are full and discounts widen.
What to watch: the natural gas price differential in the fourth-quarter report. A discount wider than the $0.35 to $0.40 full-year target set last quarter would mean local pipeline bottlenecks are eating into winter pricing.
Export Premiums For Gas Liquids Shrank Again
Range sells propane and butane through East Coast export terminals, which lets it earn a premium over the domestic Mont Belvieu benchmark price. In the first half of 2026, global shipping disruptions pushed that premium to record levels and drove earnings beats.
As international markets calmed in the third quarter, the producer's pre-hedge NGL premium narrowed to $1.54 per barrel over Mont Belvieu, down from $3.49 in the second quarter and $4.41 in the first quarter. Total pre-hedge NGL prices still rose 24.7% from a year ago to $27.54 per barrel because underlying benchmark prices were higher than in late 2025.
The shrinking premium confirms that the outsized pricing advantage from earlier this year was temporary. As the spread returns to normal, future NGL revenue growth must come from pumping more barrels rather than wider export spreads.
What to watch: the fourth-quarter NGL price differential against the Mont Belvieu benchmark. A reading below $1.50 per barrel would show that international export advantages have returned to normal levels.
Risks This Quarter Didn't Answer
Because Range cancelled its quarterly conference call and removed its full-year financial outlook table ahead of the EQT merger, three standing questions received no update in the release.
- In-basin data-center and power contracts: management previously discussed a dozen potential deals, including the Fort Cherry project, and any signed contract announcement would validate long-term demand.
- Fixed transport commitments: second-quarter filings showed $1.1 billion of new long-term pipeline obligations, and the third-quarter 10-Q footnotes will show if commitments rose further.
- Credit rating trajectory: analysts previously questioned when the company would reach investment-grade status, a path now tied to the combined EQT balance sheet.
👓 Other Themes
Pending EQT Merger Halts Buybacks And Calls
Degner said the "pending transaction with EQT Corporation is a natural next step in our journey that will allow us to scale our business, expand our reach to meet demand and accelerate our mission." Because of the deal, the company said "Range will not host a conference call or webcast to discuss its third quarter 2026 results," and it bought back zero shares after spending $78.0 million on buybacks last quarter.
💲 Other KPIs
Cash margin per unit of production — cash revenues minus cash operating costs — rose 11.8% from $1.36 a year ago, lifting total cash margin to $350.0 million. However, it stepped down from $2.77 in the first quarter and $1.61 in the second quarter as winter gas price spikes and NGL export premiums faded.
Field operating expenses (excluding stock compensation) rose 18% from $0.11 per mcfe a year ago and matched the second quarter's $0.13 rate. That keeps field costs at the top of the $0.12 to $0.13 full-year plan set last quarter, even with 12.2% higher production volume spreading fixed field costs.
Weighted average diluted shares fell 1.7% from 239.0 million a year ago and 0.5% from 236.2 million in the second quarter. The reduction reflects the 2.8 million shares bought back in the first half of 2026 before the company paused repurchases in the third quarter.
🔮 Guidance
Unchanged. The operational plan still calls for turning 68 Appalachian wells to sales this year (50 liquids-rich and 18 dry gas), up 44.7% from 47 wells in 2025. With 55 wells connected through September, by our math that leaves 13 well connections for the fourth quarter, down from 17 in the third quarter and 21 in the second quarter.
Unchanged. Range did not publish its full guidance table, but stated that third-quarter capital spending of $170 million represented "approximately 25% of the annual 2026 budget". By our math, that points to a full-year budget near $680 million, inside the prior $650 million to $700 million range, and leaves about $149 million of spending for the fourth quarter.
❓ Key Questions
What are the terms and timeline for the EQT merger?
The earnings release mentions a pending merger with EQT Corporation and a forthcoming Form S-4 proxy filing, but gives no closing timeline, exchange ratio, or required regulatory conditions.
Did full-year production and cost targets change?
Range omitted its customary full-year guidance table for production, unit costs, and price differentials. Third-quarter output of 2.50 Bcfe per day already topped the prior 2.35 to 2.40 Bcfe per day annual range.
Why did the regional natural gas discount widen in Q3?
The natural gas differential to NYMEX widened to minus $0.55 per mcf from minus $0.47 in the second quarter, sitting below the prior full-year target of minus $0.35 to $0.40 per mcf.
Are in-basin power plant talks paused during the merger?
Management previously highlighted ongoing negotiations to supply natural gas to local data-center and power projects. Without a conference call, investors have no visibility on whether those talks continue independently.