Kimbell Royalty Partners Highlights Stability in Earnings Call

Kimbell Royalty Partners ((KRP)) has held its Q4 earnings call. Read on for the main highlights of the call.

Kimbell Royalty Partners’ latest earnings call struck a notably upbeat tone, with management emphasizing record reserves, higher distributions and a stronger balance sheet despite pockets of commodity price and production uncertainty. Executives portrayed the partnership as well positioned for tax-efficient income and disciplined growth, even as gas realizations and capital structure clean-up remain key watch points.

Permian-Focused Mabee Ranch Deal Deepens Growth Engine

Kimbell highlighted its $230 million acquisition of mineral and royalty interests under the Mabee Ranch in the Midland Basin, completed in early 2025. The deal cements the Permian as the partnership’s core growth engine, reinforcing it as the leading contributor to current production, operator activity and future drilling inventory.

Rising Distributions and Fully Tax-Efficient Payouts

Management underscored another step-up in cash returns, declaring a Q4 2025 distribution of $0.37 per common unit, up 6% sequentially. For the full year, unitholders received $1.60 per unit, with 100% treated as return of capital, effectively avoiding dividend income taxes while Q4’s payout represented roughly 75% of available cash.

Record Proved Reserves Support Production Stability

Proved developed reserves climbed about 8% in 2025 to a record near 73 million Boe, reinforcing long-term asset depth. Q4 run-rate production of 25,627 Boe per day came in above guidance midpoint, and 2026 guidance holds steady at 25,500 Boe per day, signaling a strategy focused on stability over aggressive volume growth.

Solid Q4 Revenue and Disciplined Cost Control

Fourth-quarter oil, gas and NGL revenues reached $76.0 million, driving consolidated adjusted EBITDA of $64.8 million and underscoring resilient cash generation. Cash G&A was kept tight at $6.2 million in Q4, or $2.63 per Boe, with full-year G&A at $2.51 per Boe, finishing below the midpoint of management’s own cost guidance.

Credit Facility Extension Bolsters Liquidity and Lowers Cost

The partnership’s amended credit agreement, signed in December 2025, reaffirmed a $625 million borrowing base while cutting borrowing costs by 35 basis points and extending maturity to late 2030. At year-end, Kimbell had $441.5 million drawn, net leverage of roughly 1.5 times trailing EBITDA and around $183.5 million of undrawn capacity providing ample financial flexibility.

Robust Rig Activity and Line-of-Sight Inventory

Operational momentum remains strong, with 85 rigs running on Kimbell’s acreage, representing about 16% of all U.S. land rigs. Management noted that line-of-sight wells already exceed what is required to hold production flat, pointing to resilient development activity by operators and a deep inventory of future drilling locations.

Barnett-Woodford Upside and Multi-Basin Consolidation Potential

Kimbell highlighted a key structural advantage in owning all depths across much of its mineral footprint, particularly around Barnett-Woodford development. This gives the company upside if operators accelerate drilling without Kimbell funding test wells, while management also sees room to be a leading consolidator in a U.S. royalty market it sizes at over $650 billion.

Gas Realization Pressure from Waha Exposure

Natural gas realizations came under pressure as differentials widened seasonally from 18% in Q3 to 24% in Q4, reflecting a six-point deterioration. About 15% of the partnership’s gas volumes are tied to Waha pricing, which has been structurally weak, creating a headwind for that slice of production even as liquids pricing held steady.

Flat 2026 Production Reflects Non-Operated Model

Kimbell’s 2026 production midpoint is unchanged year over year at 25,500 Boe per day, signaling reliability rather than growth and consistent with its role as a non-operating royalty owner. Management emphasized that operator-controlled development cadence, not Kimbell’s own capital spending, ultimately drives short-term volume trajectories on its acreage.

Slightly Higher Maintenance Well Bar Reflects Acquisitions

The net line-of-sight maintenance well assumption ticked up to 6.8 from 6.5, a modest increase driven mainly by the Boren acquisition and related inventory. This implies a slightly higher level of drilling activity required to keep production flat but was framed as manageable given the strong rig count and visible operator plans.

Managing Remaining Mezzanine Capital with Flexibility

After redeeming half of its Series A cumulative convertible preferred units in mid-2025, Kimbell still has some mezzanine or preferred capital outstanding. Management signaled an intent to pursue additional redemptions in the second half of 2026, but only when they strike the right balance between lowering financing costs and preserving flexibility for future M&A.

Seasonal and Structural Volatility in Commodity Realizations

Oil and NGL differentials were stable quarter over quarter, but management flagged seasonal winter widening in gas differentials as a source of earnings volatility in Q4 and Q1. Longer term, they expect relief for Waha-linked gas as new takeaway capacity ramps later this decade, but pricing and basis risk will remain a variable to monitor.

Guidance Points to Steady Volumes and Balance Sheet Discipline

For 2026, Kimbell is guiding to flat production around 25,500 Boe per day with an only modestly higher maintenance well requirement, leaning on its 85-rig footprint and record 73 million Boe of proved developed reserves. The partnership plans to keep distributions tax-efficient, allocate the remaining 25% of operating cash flow toward reducing revolver borrowings and stay opportunistic on both mezzanine redemptions and accretive deals.

Kimbell’s earnings call painted a picture of a royalty franchise leaning into scale, balance sheet strength and tax-advantaged payouts rather than headline production growth. With the Permian acquisition, record reserves and disciplined leverage, investors are being offered a stable income story with embedded optionality in gas pricing, future consolidation and multi-basin development over the next cycle.