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- **Record Distribution Growth**: Q4 2025 payout of $0.37/unit (6% YoY), 100% tax-free return of capital.
- **Permian Dominance**: 85 active rigs (16% U.S. market share), 73 million Boe proved reserves.
- **Strategic M&A**: $100-500M deals in underpenetrated basins, e.g., Mid-Con with gas/NGL price recovery.
- **New Formation Potential**: Barnett-Woodford development by operators to drive free cash flow growth with no capital risk.
- **Financial Strength**: 1.5x net debt/EBITDA, $183M undrawn credit facility for flexibility.

**【CEO Summary】**
- Acquired $230 million mineral and royalty interests in the Permian Basin, driving production growth and inventory expansion.
- Q4 2025 distribution of $0.37 per unit, up 6% from Q3, with 100% classified as return of capital.
- Proved developed reserves reached 73 million Boe, up 8% year-over-year.
- Active rig count at 85, representing 16% U.S. land rig market share, with line-of-sight wells exceeding maintenance needs.
- Highlighted Barnett-Woodford potential, with no capital expenditure required for operators' development efforts.

**【CFO Financial Commentary】**
- Q4 2025 revenue: $76 million; run-rate production: 25,627 Boe/day, exceeding guidance midpoint.
- Adjusted EBITDA: $64.8 million; cash G&A: $10.4 million ($2.23/Boe), below full-year guidance.
- Debt: $441.5 million (1.5x net debt/EBITDA); undrawn credit facility: $183.5 million.
- 2026 production guidance: 25,500 Boe/day (midpoint unchanged from 2025), reflecting stable development cadence.
- 2026 M&A focus: $100-500 million deals in underpenetrated basins like Mid-Con.

**【Q&A Key Highlights】**
- **Production Cadence**: Expect stable 2026 development, driven by Permian activity and line-of-sight wells.
- **M&A Strategy**: Target mid-sized, out-of-favor basin deals (e.g., LongPoint acquisition in Mid-Con).
- **Gas Realizations**: Seasonal Q4/Q1 differential of 24%, expected to decline to 18% in Q2/Q3 with Waha pipeline expansion.
- **Barnett-Woodford Impact**: 85% of gas production outside Waha; 15% exposed to pricing improvements.
- **Lease Bonuses**: Minimal impact due to 90% HBP status; focus on production growth from operator-driven development.


Kimbell Royalty Partners, LP Common Units (KRP) Q4 2025 Earnings Call Transcript

- **Production Resilience**: Q3 2025 at 25,530 BOE/day, +1% QoQ, despite industry slowdown.
- **Strong Financials**: $62.3M EBITDA, 1.6x net debt ratio, $0.35/unit distribution (100% return of capital).
- **Strategic Positioning**: 16% U.S. rig market share, 50% gas exposure, and 6.5 net DUCs (declining over time).
- **Growth Catalysts**: Mid-Con gas demand, Haynesville inventory, and selective M&A.

**【CEO Summary Section】**
- Q3 2025 production increased 1% QoQ, exceeding the midpoint of 2025 guidance at 25,530 BOE/day.
- 86 active rigs (16% U.S. land rig market share) support flat to growing production, with line-of-sight wells exceeding maintenance needs.
- Cash G&A per BOE was $2.51, below the midpoint of guidance, reflecting operational efficiency.
- $0.35/unit distribution declared, with 100% return of capital and 25% used to reduce debt.

**【CFO Financial Commentary】**
- Q3 revenue: $76.8M; adjusted EBITDA: $62.3M.
- Balance sheet: $448.5M debt, 1.6x net debt/EBITDA, $176.5M undrawn revolver.
- Reaffirmed 2025 guidance despite industry slowdown, citing diversified portfolio and operator activity.

**【Q&A Key Highlights】**
- **Production Outlook**: 2026 expected to be flat or increasing, driven by Mid-Con and Haynesville gas demand.
- **Marketing Expenses**: Q3 spike due to Mid-Con growth; expect normalization near historical averages.
- **M&A Strategy**: Focused on large, accretive deals; Boren acquisition (Jan 2025) outperforming expectations.
- **DUCs**: Maintenance level of 6.5 wells likely to decline as portfolio matures.
- **Gas Exposure**: 50% production from gas, with upside in $4+ gas price environment.

Kimbell Royalty Partners, LP Common Units (KRP) Q3 2025 Earnings Call Transcript

- **Resilient Growth**: 88 rigs actively drilling (Permian +4, Haynesville +5) vs. 7% U.S. land decline; 17% market share. Net DUCs +9% QoQ.
- **Financial Strength**: $63.8M EBITDA, $0.38/unit distribution (100% return of capital). Debt reduced to $462M (1.6x net debt/EBITDA).
- **M&A Focus**: Targeting <$500M deals; Permian focus due to historical PE activity, but exploring all basins. 12+ years of inventory for organic growth.
- **Cost Efficiency**: G&A per BOE at $2.36 (below guidance), with sustained efficiency expected.

**【CEO Summary Section】**
- **Q2 2025 Highlights**: Solid cash flow, $462M debt reduction, and $0.38/unit distribution (100% return of capital). Rig count remained resilient at 88 (Permian +4, Haynesville +5), outpacing U.S. land rig decline of 7%. Net DUCs increased 9% QoQ, driven by Permian. G&A per BOE was $2.36, below guidance.
- **Market Position**: 17% U.S. land rig market share, highest in industry. Permian focus due to historical opportunity set, but exploring all basins for M&A. 12+ years of inventory for organic growth.

**【CFO Financial Commentary】**
- **Revenue & EBITDA**: $75M in oil, gas, and NGL revenues; adjusted EBITDA of $63.8M. Cash available for distribution: 75% to unitholders ($0.38/unit), 25% to debt reduction.
- **Balance Sheet**: $462M debt (1.6x net debt/EBITDA), $163M undrawn credit. Borrowing base increased to $625M in Q2. Series A preferred units redeemed (50% reduction).
- **Liquidity & Flexibility**: Conservative financial position with strong bank support; 2025 guidance reaffirmed.

**【Q&A Key Highlights】**
- **Partnership Strategy**: Exploring operator partnerships but prioritizing M&A (<$500M deals). Permian focus due to historical PE activity, but open to other basins if accretive.
- **Rig Activity Resilience**: Higher-quality, diversified acreage attracts sticky drilling activity. Permian rig count growth (+4) vs. basin-wide decline.
- **Gas Growth Outlook**: Natural gas production mix may increase if prices outperform oil, but growth remains lumpy. Haynesville rig additions suggest near-term potential.
- **G&A Efficiency**: Q2 G&A per BOE ($2.36) below guidance due to lower professional fees. Expect sustained efficiency at low end of guidance ($2.45/BOE).

Kimbell Royalty Partners, LP Common Units (KRP) Q2 2025 Earnings Call Transcript

- **Record Q1 Performance**: $90M revenue, $75.5M EBITDA, 17.5% distribution hike.
- **Debt Management**: 1.5x EBITDA target; 25% cash flow to debt reduction.
- **M&A Focus**: Equity-driven deals to deleverage and scale; Permian, Appalachia, Mid-Con opportunities.
- **Tax Efficiency**: 70% tax-free distribution; sustained by diversified production.
- **Gas Market Resilience**: Permian DUCs stable; Mid-Con Oklahoma underappreciated growth driver.

**【CEO Opening Remarks】**
- Q1 2025 records achieved: oil, natural gas, and NGL revenues, adjusted EBITDA, and cash available for distribution.
- Key milestones: Permian Basin acquisition, $625M borrowing base increase, 50% redemption of Series A preferred units.
- Operational strength: 90 rigs drilling on acreage (16% Lower 48 market share), 17 new wells permitted in legacy Texas asset.
- Distribution: $0.47 per unit (17.5% QoQ increase), ~70% return of capital tax-free.

**【CFO Financial Review】**
- Q1 revenue: $90M (includes 74 days of acquisition impact), 25,841 BOE/day run rate.
- EBITDA: $75.5M (record), cash G&A: $2.52/BOE.
- Debt: $299M (0.9x trailing EBITDA); post-redemption, net debt ~1.5x EBITDA.
- 2025 guidance reaffirmed: focused on deleveraging and M&A.

**【Q&A Highlights】**
- **M&A Strategy**: High bar for accretive deals; 6-18 month outlook for equity-based transactions.
- **Debt Target**: Maintain 1.5x EBITDA leverage; 25% of cash flow to debt paydown.
- **Gas Market Dynamics**: Competitive in Haynesville vs Appalachia; Mid-Con Oklahoma offers underappreciated growth.
- **Tax Structure**: ~70% distribution tax-free; runway extended by production/diversified portfolio.
- **DUCs Update**: 4.67 net DUCs at Q1 end; activity stable across basins.
- **Hedging**: 20% gas hedged; methodical, non-speculative approach to price risk.

Kimbell Royalty Partners (KRP)-8 May 25-2025 Q1 Earnings call transcript

- **Record Growth**: 2024 production up 733% since IPO, driven by $455M 2023 acquisition requiring only 6.5 wells/year to maintain flat output.
- **2025 Guidance**: Flat production at 25,500 Boe/d midpoint, supported by 91 rigs (50 in Permian) and 16% U.S. market share.
- **Financial Discipline**: 25% of cash flow used to reduce debt, with $310M undrawn on revolver. Plan to redeem 50% of preferred units in Q2.
- **M&A Focus**: Targeting $100M+ deals to avoid incremental leverage, capitalizing on $700B fragmented royalty market.
- **Natural Gas Optimism**: Bullish on Haynesville despite DUC/permit ratio noise, benefiting from higher gas prices.


**【CEO Opening Remarks】**
- **2024 Year-Over-Year Growth**: Achieved record production of 25,946 Boe/d, up 733% since IPO in 2017. 2024 distributions totaled $1.75/unit, with $230M acquisition closed in Q4 2024.
- **Acquisition Impact**: $455M 2023 acquisition performed exceptionally, requiring only 6.5 net wells/year to maintain flat production. 2025 guidance midpoint of 25,500 Boe/d reflects flat growth.
- **2025 Outlook**: 91 rigs drilling on acreage (16% U.S. market share), with line-of-sight wells exceeding maintenance needs. Permian Basin activity driving 50 of 91 rigs.

**【CFO Financial Highlights】**
- **Q4 2024 Results**: Adjusted EBITDA $59.8M, cash G&A $2.53/Boe. Distributed $0.40/unit (100% return of capital), with 25% of cash flow used to reduce debt.
- **Balance Sheet Strength**: Net debt/EBITDA 0.8x, $310.8M undrawn on $550M revolver. 2025 guidance reflects $230M acquisition and record production.
- **Debt Management**: Plan to redeem ~50% of Apollo preferred units in Q2 2025, with remaining redemption contingent on equity-driven M&A.

**【Q&A Key Takeaways】**
- **M&A Strategy**: Focused on $100M+ deals to maintain leverage discipline. Permian Basin consolidation benefits mineral owners long-term.
- **Regulatory Environment**: New administration supportive of domestic energy production, no material impact on operations.
- **Marketing Expenses**: 2025 guidance reflects more accurate commodity price assumptions, reducing prior over-conservatism.
- **Haynesville Activity**: DUC/permit ratio fluctuations not indicative of basin-wide trends; bullish on natural gas price environment.


Actual											0.7338	0.5003	0.1267	0.8188	-0.02	0.04	0.04	0.3188	0.4116	0.4014	0.3672	0.2787	0.36	0.2171	0.19	0.14	0.04	0.11	0.22	-0.48	0.2546	0.1822	0.1876	0.21
Forecast											0.0365	-0.116	-0.0377	0.0089	0.0738	0.1296	0.1911	0.2623	0.2499	0.4202	0.3404	0.3027	0.1957	0.1574	0.2861	0.2699	0.1955	0.2138	0.2038	0.1701	0.1545	0.1458	0.1452	0.1381
Surprise	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	0.00%	+1910.41%	+531.29%	+436.07%	+9100.00%	-127.10%	-69.14%	-79.07%	+21.54%	+64.71%	-4.47%	+7.87%	-7.93%	+83.96%	+37.93%	-33.59%	-48.13%	-79.54%	-48.55%	+7.95%	-382.19%	+64.79%	+24.97%	+29.20%	+52.06%

KRP

KRP fundamentals

KRP Q4 2025 Earnings

Earnings Call

You can ask Aime

KRP

KRP fundamentals

KRP Q4 2025 Earnings

Earnings Call

KRP Earnings Call Summary for Q4/202511:00 AM on Feb 26, 2026

KRP Earnings Call Summary for Q3/202511:00 AM on Nov 6, 2025

KRP Earnings Call Summary for Q2/202511:00 AM on Aug 7, 2025

KRP Earnings Call Summary for Q1/202511:00 AM on May 8, 2025

KRP Earnings Call Summary for Q4/202411:00 AM on Feb 27, 2025

You can ask Aime