Range Resources Corporation (RRC) | The Buildout — AI Infrastructure
The Verdict
Range Resources is an independent natural gas producer working the Marcellus Shale in Pennsylvania, selling natural gas, NGLs and a small oil stream. For the AI buildout its role is indirect: the gas it produces can be burned to generate electricity for data centers and broader power demand, but Range does not sell AI hardware, software or data-center infrastructure, and its molecules sit several steps from the AI spend itself. What distinguishes the company is the marketing side of the business — moving NGLs to the East Coast for waterborne export and selling gas into multiple demand centers — which is what lets it report realized prices above benchmark indices rather than below them. The data-center piece is earlier stage: management describes dialogue and prospective projects, not signed volumes.
| Market Cap | — |
| Revenue (TTM) | $3.3B |
| Revenue Growth | +19.1% |
| EBITDA Margin (TTM) | 45.0% |
| Net Debt | $1.0B |
| Earnings Beats | 7 of 7 |
| P/E (TTM) | — |
| EV/EBITDA (TTM) | — |
What We Like
- The multi-year plan is on schedule: production ran 2.2 Bcfe/d in Q1 2026 and 2.3 Bcfe/d in Q2 2026, guided to 2.4 Bcfe/d in Q3 2026, 2.5 Bcfe/d exiting 2026 and ~2.6 Bcfe/d in 2027. Maintenance at 2.6 Bcfe/d is guided at under $600M of annual drilling and completion capital, about $0.60/Mcfe.
- Realized prices carry premiums rather than discounts. Q1 2026 brought an NGL premium of $4.41/bbl over Mont Belvieu, which management called the largest in company history, and a gas differential of $0.18 over Henry Hub, the best in over a decade. Q2 2026's NGL premium was $3.49/bbl, and the FY2026 guides were raised to $2.50/bbl and $0.35–$0.40/Mcf.
- Capital returns are running: $489M returned to equity holders year to date in 2026 — $105M of buybacks, $47M of dividends and $337M of debt reduction — with 35.9 million shares repurchased since the program began, a reduction of nearly 10%, and $1.5 billion of authorization remaining. The balance sheet is roughly half a turn levered.
- Drilling and completion efficiency keeps improving. Q2 2026 included a record completion quarter of nearly 1,900 frac stages with two crews, over 10 stages per day per crew, and an annualized >750,000 lateral feet for a single crew. Pad redevelopment across roughly 250 pad sites has improved efficiencies by as much as 30%.
- Management describes its GP&T contracts as "right-way risk" — costs move lower when realized prices fall, with about $0.01 of GP&T per $1/bbl move in NGLs and $0.02–$0.03 per dollar on the gas side — which it says enhances resilience through cycles.
What We’re Watching
- The 2027 natural gas macro outlook is soft, and management describes the market as "disconnected" from long-term fundamentals. Range's illustration of free cash flow exceeding $2.5 billion over three years assumes a $3.75 mid-cycle natural gas price.
- NGL premium durability: the quarterly premium fell from $4.41/bbl in Q1 2026 to $3.49/bbl in Q2 2026, and management said international netbacks have normalized since June. The FY2026 guide of $2.50/bbl assumes normalization from crisis-level peaks.
- Demand conversion: there is no signed data-center contract, no volume and no timeline. Fort Cherry, named on the Q1 2026 call as a data-center/power location, was not updated by name in Q2 2026.
- Infrastructure timing: the second-half ramp depends on processing commissioning, with "meaningful volumes" expected by August 2026. A delay pressures the 2.5 Bcfe/d exit-2026 target.
On the two calls in evidence, the thesis is intact and modestly strengthening on operations: production is tracking the multi-year plan, the NGL guide was raised twice, a new full-year gas differential guide was added, buybacks accelerated from $27M in Q1 to $78M in Q2, and debt fell by $337M year to date. The parts that would make it a different story are still unproven — the demand-pull pipeline remains dialogue, the differentials have already come down from their Q1 peak, and the 2027 gas curve has softened. The open question is whether the data-center and power conversations convert into signed, multi-year agreements with disclosed volumes before growth beyond the current plan needs them.
Earnings Beat
Q2 2026 revenue was $834M at a 58.7% gross margin. Production was 2.3 Bcfe/d, with capital spending of $222M as the company added a second completion crew and a spot horizontal rig. The standout was completions: two crews finished nearly 1,900 frac stages, which management called the best quarterly performance in Range's history, at over 10 stages per day per crew.
| Metric | Q2 FY2026 | Q1 FY2026 | Q2 FY2025 | YoY |
|---|---|---|---|---|
| Revenue | $834M | $1.0B | $700M | +19.2% |
| Gross margin | 58.7% | 63.0% | 35.1% | +2360bps |
| EBITDA | $418M | $522M | $279M | +49.7% |
| EPS | $0.83 | $1.45 | $0.99 | −16.6% |
| Production (Bcfe/d) | 2.3 | 2.2 | n/a | — |
| Frac stages completed | ~1,900 | 874 | n/a | — |
we could see the ability to double the size of the organization's production just in a matter of a few years.— Dennis Degner, CEO, 2026-07-22
Management tone: On the Q2 2026 call management stayed direct on operational and capital questions, giving quarterly production and capital cadence, rig and crew counts, and DUC sequencing. It reframed the credit-rating question rather than deflecting it, and declined to disclose NGL contract terms, saying "No. There is some competition in this business, as you'd expect." The tone moved more expansive than the prior call: post-2027 language shifted from "another wedge" of growth to openly discussing doubling production, while management kept conditioning the ambition on demand pull and margin visibility.
Management Guidance
For FY2026, Range guides capital spending of $650–$700M, an NGL differential of a $2.50/bbl premium over Mont Belvieu, and a natural gas differential of $0.35–$0.40/Mcf over Henry Hub, with a production mix of ~65–70% liquids and ~30–35% dry gas. Production is guided to 2.4 Bcfe/d in Q3 2026, 2.5 Bcfe/d exiting 2026, and ~2.6 Bcfe/d in 2027. Q3 2026 capital should look similar to what was seen in Q1 ($139M) and Q2 ($222M), and Q4 2026 returns to one horizontal rig and one frac crew with capital more in line with Q1. 2027 capital is expected to be similar to 2026, and maintenance at 2.6 Bcfe/d is guided at less than $600M of annual drilling and completion capital, or about $0.60/Mcfe.
Trajectory
Revenue over the last four quarters has been a price story more than a volume story: $656M in Q3 FY2025, $787M in Q4 FY2025, $1,034M in Q1 FY2026 and $834M in Q2 FY2026. In Q1 FY2026 the realized consolidated price rose to $5.09/Mcfe from $4.00/Mcfe a year earlier while total production was essentially flat year over year (198.7 Bcfe versus 198.0 Bcfe), so the quarter was a price event, not a volume event. Margins have widened: gross margin was 58.7% in Q2 FY2026 against 35.1% in Q2 FY2025, and EBITDA margin 50.1% against 39.9%. Volume is only starting to contribute — production ran 2.2 Bcfe/d in Q1 2026 and 2.3 Bcfe/d in Q2 2026, with the ramp to 2.5 Bcfe/d by year-end tied to mid-year processing commissioning.
The Model
The model's locked projections put FY+1 revenue at $3,671M with EBITDA of $1,817M, a 49.5% margin, then FY+2 revenue at $3,850M with EBITDA of $1,852M, a 48.1% margin. Across the five runs behind those medians, the FY+2 revenue spread is 15%, from $3,701M to $4,285M. The near-term anchor is the guided production path — 2.4 Bcfe/d in Q3 2026, 2.5 Bcfe/d exiting 2026 and ~2.6 Bcfe/d in 2027 — plus the raised NGL and gas differential guides. FY+2 depends on whether production holds near 2.6 Bcfe/d, whether the differentials survive normalization, and whether the 2028 demand-pull decision adds volumes or leaves the plan flat.
| Metric | FY2025 | Next FY (E) | Following FY (E) |
|---|---|---|---|
| Revenue | $3.0B | $3.7B | $3.9B |
| YoY Growth | — | +22.8% | +4.9% |
| EBITDA | $1.2B | $1.8B | $1.9B |
| EBITDA Margin | 41.2% | 49.5% | 48.1% |
Projections are the median of 5 independent model runs. The model’s revenue sits 16.3% above analyst consensus.
For FY2026, Range guides capital spending of $650–$700M, an NGL differential of a $2.50/bbl premium over Mont Belvieu, and a natural gas differential of $0.35–$0.40/Mcf over Henry Hub, with a production mix of ~65–70% liquids and ~30–35% dry gas. Production is guided to 2.4 Bcfe/d in Q3 2026, 2.5 Bcfe/d exiting 2026, and ~2.6 Bcfe/d in 2027. Q3 2026 capital should look similar to what was seen in Q1 ($139M) and Q2 ($222M), and Q4 2026 returns to one horizontal rig and one frac crew with capital more in line with Q1. 2027 capital is expected to be similar to 2026, and maintenance at 2.6 Bcfe/d is guided at less than $600M of annual drilling and completion capital, or about $0.60/Mcfe.
What Could Go Right — and Wrong
- A signed data-center or power supply agreement with disclosed volume, duration and indexation would convert the demand pipeline into contracted revenue.
- The FY2026 differential guides holding into 2027 through full shoulder seasons — a $2.50/bbl NGL premium and a $0.35–$0.40/Mcf gas premium — would support the durable-margin case.
- Processing commissioning lands by August 2026 and the production path holds at 2.4 Bcfe/d in Q3 2026, 2.5 Bcfe/d exiting 2026 and ~2.6 Bcfe/d in 2027.
- Formal 2028+ growth guidance tied to named demand; management describes an over-3-Bcf/d scenario — two rigs, two crews, another 900,000 lateral feet — as "very possible" within a 12–18 month timeframe.
- Export infrastructure arrives on schedule: Repauno in service in January 2027 and about 360,000 bbl/d of additional LPG capacity via two new terminals early in 2027.
- The 2027 gas curve stays soft; the three-year free cash flow illustration depends on a $3.75 mid-cycle natural gas price.
- NGL netbacks revert further and the premium compresses toward the benchmark, weakening the differentiated-margin story.
- Processing commissioning slips past August 2026, pressuring the 2.5 Bcfe/d exit-2026 target and the 2027 leg of the plan.
- The demand pipeline stays dialogue; Permian associated gas or other supply fills incremental demand first.
- Third-party midstream dependence and GP&T costs — GP&T was $323.3M in Q1 2026, up on higher electricity and fuel prices, and transportation renewals approaching 15-year marks could reset the economics.
Looking Ahead
Over the next 12 months the test is execution plus conversion. The processing commissioning that management says brings "meaningful volumes" by August 2026 has to land for the production path to reach 2.4 Bcfe/d in Q3 2026 and 2.5 Bcfe/d exiting the year. Beyond that, Repauno goes into service in January 2027 and about 360,000 bbl/d of additional LPG capacity arrives via two new terminals early in the new year, both supporting the export-linked NGL premium, and the 10-year Midwest power plant deal starts up in late 2027. What is not yet on the calendar is a signed data-center contract.
- August 2026Processing commissioning — Meaningful volumes expected to flow; underpins the 2.5 Bcfe/d exit.
- Q3 2026Q3 production print — Guided to 2.4 Bcfe/d; first read on the mid-year infrastructure.
- Q4 2026Return to one rig — One horizontal rig and one frac crew; capital back toward Q1's $139M.
- January 2027Repauno in service — NGL export terminal starts up, supporting East Coast waterborne sales.
- Early 2027New LPG capacity — About 360,000 bbl/d via two new terminals, per management.
- Late 2027Midwest power start-up — Ten-year power plant deal begins deliveries; counterparty unnamed.
Financials
Annual Summary
| Metric | FY2024 | FY2025 | TTM | YoY |
|---|---|---|---|---|
| Revenue | $2.3B | $3.0B | $3.3B | +27.7% |
| Gross Margin | 23.8% | 34.8% | 47.9% | +1,102bps |
| EBITDA | $706M | $1.2B | $1.5B | +74.4% |
| EBITDA Margin | 30.2% | 41.2% | 45.0% | +1,104bps |
| Net Income | $266M | $658M | $860M | +147.1% |
| Free Cash Flow | $318M | $1.0B | $1.2B | — |
| Net Cash | — | — | — | — |
Key Ratios (Trailing)
- P/E TTM—
- EV/EBITDA TTM—
- EV/Revenue TTM—
- Price/FCF TTM—
- Gross Margin (TTM)47.9%
- EBITDA Margin (TTM)45.0%
- Net Margin (TTM)26.0%
- ROIC15.3%
- FCF Conversion78.8%
- SBC / Revenue2.1%
The Company
Range Resources is a Fort Worth, Texas-based independent producer of natural gas, NGLs and oil in the Appalachian region, with its principal operations in the Marcellus Shale in Pennsylvania. The company's stated objective is to build stockholder value through returns-focused development of those properties, and it reports a single segment with one company-wide management team. Its relevance to the AI buildout is indirect: natural gas is a fuel that can be burned to generate electricity for data centers and broader power demand.
Range owns wells and acreage, not midstream or processing assets — the 10-K lists no plants and flags as a risk that the business depends on transportation and NGL processing facilities owned by others. That shapes the model: growth and premium realizations both ride on third-party gathering, processing, fractionation and export infrastructure, and on a marketing portfolio that reaches East Coast waterborne export and multiple demand centers. Operations run through a blocky acreage position that lets Range return to existing pads — roughly 250 pad sites, about one-third of them revisited — reusing roads, pads and production infrastructure. Efficiency comes from drilling and completions: management says 20,000-foot laterals are now being drilled, with the average approaching 12,000 to 15,000 feet and some opportunities touching 18,000 to 20,000 feet.
Business Segments
Competitive Landscape
Range competes as one of several Marcellus gas producers, and on the commodity itself the molecules are fungible. Management's argument rests on things it describes as harder to replicate at scale: a large blocky acreage position with multi-decade inventory, proximity to East Coast export, diversity of outlets, and the marketing portfolio. Degner's own summary of why counterparties call is "proximity, diversity, and also inventory… probably most importantly, the last one." Competitors are increasingly described as competing in data-center gas supply as well as Marcellus natural gas production.
- Listed as a competitor in Marcellus natural gas production and data-center gas supply; also appears in the wiring data as a supplier of the Range Resources Header pipeline (0.6 Bcf/d) for dry gas takeaway.
- CNX ResourcesNamed as a competitor in Marcellus natural gas production and data-center gas supply; not discussed individually.
- Antero Resources (AR)Named as a competitor in Marcellus natural gas production and data-center gas supply; not discussed individually.
- Coterra Energy (CTRA)Named as a competitor in Marcellus natural gas production and data-center gas supply; not discussed individually.
- Expand Energy (EXE)Named as a competitor in Marcellus natural gas production and data-center gas supply; not discussed individually.
Supply Chain
Range sits upstream and depends on third parties for everything past the wellhead — gathering, processing, fractionation, transportation and export terminals. Its 10-K flags that dependence as a risk, and no neighbor transcript in the source set names Range.
More on RRC: Earnings recap