Granite Ridge Resources (GRNT) Q1 2026 earnings review
Volume Growth Overshadowed by Runaway Operating Costs
Granite Ridge delivered a textbook case of profitless volume growth in 26Q1. While daily production surged 18% YoY to 34,467 Boe/d and total revenue crept up 4% to $128.3M, the bottom line cratered. A massive $60.2M mark-to-market derivative loss drove a GAAP net loss of $47.0M, but the core business is also bleeding: Adjusted Net Income collapsed 89% to $3.1M. The culprit is a severe loss of cost control. Lease operating expenses (LOE) skyrocketed 55% YoY. Management continues to outspend cash flow to fuel acquisitions, pushing leverage to 1.3x—breaching their own previously stated target ceiling of 1.25x.
🐂 Bull Case
The Operated Partnership model continues to deliver on the top line. Daily production volumes are Accelerating, growing 18% YoY to reach 34,467 Boe/d, proving the company can successfully source and execute inventory.
Despite broader macro volatility, GRNT realized $69.94 per barrel of oil (excluding derivatives), Stable compared to $69.18 a year ago. This shielded the top line from the severe weakness seen in natural gas.
🐻 Bear Case
Top-line volume growth is failing to translate into cash. LOE spiked 55% to $9.57/Boe, dragging Adjusted EBITDAX down 22% YoY despite the 18% jump in production. Margins are being severely compressed by saltwater disposal and service costs.
Net Debt to TTM Adjusted EBITDAX hit 1.3x. Management spent 2025 emphasizing a strict 1.0-1.25x leverage ceiling and a 'pivot to free cash flow.' Hitting 1.3x indicates they are still prioritizing M&A over balance sheet discipline.
⚖️ Verdict: 🔴
Bearish. Top-line volume growth is failing to mask severe cost inflation and margin deterioration. When per-unit operating costs rise 55% and leverage creeps past management's own targets, the M&A-driven growth story loses its luster.
Key Themes
Runaway Lease Operating Expenses
LOE is Accelerating dangerously. Unit costs hit $9.57/Boe, a massive 55% YoY increase from $6.17 in 25Q1. Management praised robust well performance and a rigid 25% IRR underwriting threshold, but this positive narrative is contradicted by the severe cost inflation driven by water cuts, flowback operations, and contract labor. If costs remain at this level, underwritten IRRs will quickly evaporate.
Financial Flexibility is Decelerating
In late 2025, management promised a strategic pivot toward free cash flow generation and a strict Net Debt to EBITDAX target of 1.0-1.25x. In 26Q1, they reported a ratio of 1.3x. The company continues to outspend its Operating Cash Flow ($58.3M) with Capital Expenditures ($68.4M). This constant debt-funded M&A engine is eroding balance sheet safety.
Operated Partnership Sourcing Engine
The Operated Partnership program remains a Stable and effective driver for inorganic growth. This unique investment structure allows GRNT to source unit-by-unit deal flow. In 26Q1, they successfully closed 17 acquisitions in the Delaware and Utica Basins, securing 3.0 net undeveloped locations at attractive entry multiples.
Macro Headwinds: Natural Gas Realizations Reversing
Broader macro pressure in the natural gas market is weighing heavily on the portfolio. Realized natural gas prices crashed 36% YoY, dropping from $3.97/Mcf in 25Q1 down to $2.55/Mcf in 26Q1. Until gas-to-power infrastructure or new pipeline capacity alleviates Permian basin bottlenecks, gas volumes will continue to drag down blended margins.
Volume Output Continues to Scale
Despite margin issues, sheer volume output is Accelerating. The company brought 1.4 net wells online in Q1, driving an 11% YoY increase in daily oil production (16,433 Bbls/d) and a 24% YoY increase in daily natural gas production (108,200 Mcf/d). The ability to consistently execute drilling programs across multiple basins is a core operational strength.
Other KPIs
Decelerating. Down 22% from $91.4M a year ago. This is the clearest indicator of the margin squeeze: the company produced 18% more hydrocarbons per day, yet generated significantly less cash earnings due to soaring lease operating expenses and weaker gas realizations.
Reversing sharply. Down 89% from $28.9M in 25Q1. GAAP Net Income was devastated by a $60.2M mark-to-market derivative loss and an $11.2M impairment, but even after adjusting for these non-cash items, core profitability has almost entirely evaporated.
Decelerating compared to 25Q1's $76.1M. Cash generation is trailing capital expenditures ($68.4M), forcing the company to draw an additional $40M from its credit facilities during the quarter to fund development, acquisitions, and the $0.11 quarterly dividend.
Guidance
Stable. The midpoint of 35,000 Boe/d represents roughly 9% YoY growth from FY25's average of ~32,000 Boe/d. Sequentially, this implies flat to slightly higher production compared to the 34,467 Boe/d achieved in 26Q1.
Reversing. For this guidance to be accurate, LOE must drop significantly from the $9.57/Boe printed in 26Q1. Achieving the $8.25 midpoint will require major operational efficiencies or a rapid resolution to the current saltwater disposal and contract labor inflation.
Stable to slightly Decelerating. The $365M midpoint is roughly aligned with the company's historical run-rates but indicates a moderation in growth spending compared to the peak acquisition sprees of early 2025, aligning with their stated goal of eventually prioritizing free cash flow.
Key Questions
Bridge to Lower LOE
Lease operating expenses hit $9.57/Boe in Q1, driven by structural issues like water cuts and service rates. Yet, your full-year guidance suggests a midpoint of $8.25/Boe. What specific operational interventions give you confidence that costs will reverse so sharply in the coming quarters?
Leverage Discipline
Net Debt to EBITDAX has crept up to 1.3x, breaching your previously stated comfort zone of 1.0-1.25x. Does this trigger an automatic slowdown in your Operated Partnership acquisition engine, or are you willing to stretch the balance sheet further for the right deals?
Impairment Color
You recorded an $11.2M non-cash impairment this quarter. Which specific assets or basins drove this write-down, and does it change your underwriting assumptions for future inventory additions in those areas?