Kimbell Royalty Partners (KRP) Q3 2026 earnings review
Kimbell's acquisitions lift oil output, but new units slow per-unit cash
Kimbell Royalty Partners, which collects oil and gas royalties from land across 28 states, grew its total output through acquisitions while per-unit cash fell from last quarter. Daily production reached a record 27,565 barrels of oil equivalent, and commodity sales rose 26% from a year ago on higher oil prices. Chief executive Robert Ravnaas kept the fourth-quarter outlook unchanged and expects cash flow to rise next quarter because 84% of oil output is unhedged.
| Daily production | 27,565 Boe/d +8% from a year ago; 28,910 exit rate |
|---|---|
| Oil, gas and NGL revenue | $96.9M +26% from a year ago on higher oil prices |
| Distributable cash per unit | $0.54 +15% from a year ago, down from $0.59 in Q2 |
| Fourth-quarter outlook | Unchanged affirmed post-deal targets; expects higher Q4 cash flow |
⚖️ Verdict: ⚪ Neutral
The story is unchanged because the summer buying spree solved one standing worry while enlarging two others. Buying $367 million of mineral rights since June rebuilt the backlog of future wells to 14% above the level needed to hold output flat, easing our concern about stalling volume. The bad news: paying for those deals with new units increased the unit count by 15% from a year ago, which cut into per-unit gains, and borrowing $100 million to buy back half the remaining preferred units will push bank debt over $615 million by our math.
The question now is whether the enlarged land base can grow cash per unit without relying on higher oil prices. Either the 93 active rigs turn the record well backlog into per-unit volume growth, or the new units and higher bank debt eat up the extra barrels. Fourth-quarter distributable cash per unit, the first full period after the August acquisition, will tell.
🐂 Bull Case
Acquisitions Lifted Output and Rebuilt Well Inventory
Kimbell owns mineral rights in oil and gas land and collects a share of sales without paying drilling costs. The partnership closed $367 million of purchases since June, including a $221.2 million deal on August 21. Those deals pushed output to a record 27,565 barrels of oil equivalent per day (Boe/d, which combines oil and gas into one volume measure).
- Daily output after the August deal closed: 28,910 Boe/d, up 12% from the second-quarter average by our math
- Drilled but uncompleted wells (DUCs) and permits: 9.37 net wells, up from 7.39 last quarter
- Wells needed per year to hold output steady: 8.20 net wells, up from 7.20 last quarter
- Active rigs on Kimbell land: 93, up 2 from last quarter and equal to 16% of all US land rigs
For the past year, the number of wells in the pipeline sat barely above the level needed to keep production from falling. The new land raised that maintenance hurdle by one full well, but it added almost two net wells to the pipeline, lifting the buffer to 14% above maintenance by our math.
What to watch: fourth-quarter daily production against the 28,910 Boe/d exit rate. A reading above that level would show that the 93 active rigs are adding volume on existing land, not just via buyouts.
Higher Oil Prices Lift Payouts and Tax Shield
Because Kimbell pays zero drilling capital, it sends 75% of its distributable cash to unitholders and uses 25% to pay down bank debt. Third-quarter oil prices averaged $86.18 a barrel, up 34% from $64.21 a year ago by our math, which lifted the quarterly payout to $0.45 per unit from $0.35 a year earlier.
The tax treatment improved as well. Chief executive Robert Ravnaas said 76% of the payout should count as "return of capital and not subject to dividend taxes". That tax-free share had dropped from 100% last year to 47% in the second quarter, so the new asset base restored the tax shield.
What to watch: the fourth-quarter distribution and its return-of-capital share. A higher payout alongside a tax-free share above 70% would confirm that the summer acquisitions permanently expanded the tax shield.
🐻 Bear Case
Issuing Units for Deals Diluted Per-Unit Gains
Management highlights record total production and cash flow from its $367 million buying spree, including the $221.2 million August purchase from affiliates of its sponsors. However, Kimbell paid for a large part of these properties by handing out new partnership units, which spreads the cash across many more owners.
- Total cash available for distribution: $57.4 million, up 32% from $43.5 million a year ago
- Cash available for distribution per unit: $0.54, up 15% from a year ago, but down 8% from $0.59 last quarter
- Total common and Class B units: 124.2 million, up 15.1% from 107.9 million a year ago by our math
Unit growth ate up more than half of the cash flow gain from a year ago. Even if we include $7.1 million of pre-closing cash from the August deal that did not count in third-quarter earnings, the enlarged unit count keeps per-unit growth well behind headline volume growth. The release also gave no separate well counts for existing land versus bought land.
What to watch: cash available for distribution per unit in the fourth quarter, the first full period with the August deal and the higher unit count. It needs to beat $0.59 to beat the pre-deal second-quarter peak.
Redeeming Preferred Units Adds to Bank Debt
On October 16, Kimbell gave notice to buy back half of its remaining Series A preferred units, which sit ahead of common units for payouts. Ravnaas said the move "further simplifies our capital structure and reduces our cost of capital". The catch is how Kimbell is paying for it: the $100.2 million buyout is "expected to be funded with borrowings under the Company's secured revolving credit facility".
Credit line debt already climbed from $478.7 million in June to $535.8 million in September to help pay for the August acquisition, lifting net debt to 1.5 times yearly profit excluding one-offs, up from 1.4 times. By our math, adding $100.2 million of preferred buyout debt and subtracting $18.8 million of third-quarter debt paydown pushes bank debt to about $617 million against a $750 million credit limit.
What to watch: net debt to yearly Adjusted EBITDA at year-end after the November 16 buyout closes. A jump above 1.7 times would move the partnership further away from its long-term goal of 1.0 times.
Unhedged Oil Exposure and Weak Gas Prices
"Based on current quarter oil prices, we expect a material increase in cash flow in Q4 2026, especially since approximately 84% of our estimated Q4 2026 oil production is unhedged," Ravnaas said. Leaving barrels unhedged helps when prices climb, but the third quarter showed the downside of that bet.
Realized oil prices cooled 9% from the second quarter's $94.67 per barrel down to $86.18, which pulled the quarterly cash payout down from $0.47 per unit to $0.45. Meanwhile, natural gas makes up 45% of volume and remains a drag at $2.21 per thousand cubic feet, down 10.5% from a year ago by our math, while hedge contracts lost $13.1 million on paper as forward prices moved.
What to watch: fourth-quarter realized oil and natural gas prices. Because only 16% of fourth-quarter oil is locked in with swaps at $63.33 a barrel, any oil price drop directly cuts the cash payout.
💲 Other KPIs
Uncollected cash from commodity sales jumped 64.9% from a year ago and rose $14.3 million from last quarter as Kimbell added the newly bought wells. Because that cash had not arrived by September 30, operating cash flow fell 7.4% from a year ago to $58.1 million even though commodity revenue grew 26.1%.
General and administrative overhead totaled $10.7 million, up 6.0% from a year ago. Divided across higher production, cash overhead came in at $2.48 per Boe (down from $2.50 last quarter and $2.51 a year ago), while non-cash unit compensation fell to $1.73 per Boe from $1.85 last quarter.
🔮 Guidance
Unchanged. The partnership kept the fourth-quarter production and cost targets it issued in a separate August 24 release after closing the $221.2 million acquisition, though it did not reprint the numbers in today's table. Management pointed to the post-deal run rate of 28,910 Boe/d and expects higher fourth-quarter cash flow on stronger oil prices.
❓ Key Questions
What are the exact Q4 and 2027 production targets?
The earnings release affirmed the fourth-quarter outlook from August 24 without printing the numbers. Investors need the exact volume and cost ranges, plus a first look at the 2027 maintenance well hurdle.
How many pipeline wells came from existing land?
Net drilled-uncompleted wells and permits rose by 1.98 to 9.37, while the maintenance hurdle rose by 1.00 to 8.20. Management did not disclose whether pipeline wells on pre-acquisition land grew or shrank.
How was the sponsor-affiliated buyout priced and reviewed?
The $221.2 million August acquisition came from affiliates of Kimbell's sponsors in exchange for cash and units. The release did not detail the conflicts-committee review or the stand-alone depletion rate of those wells.
When will bank debt return to the 1.0x target?
Funding the $100.2 million preferred unit buyout on the credit line will push bank debt past $615 million by our math. Management has not said whether it will pause cash acquisitions while paying that down.