Kimbell Royalty Partners Announces Second Quarter 2025 Results

Rhea-AI Summary

Kimbell Royalty Partners (NYSE:KRP) reported strong Q2 2025 results with run-rate daily production of 25,355 barrels of oil equivalent (Boe) per day. The company announced a quarterly cash distribution of $0.38 per common unit, representing a 10.3% annualized yield. Key financial metrics include $74.7 million in oil, natural gas, and NGL revenues, net income of $26.7 million, and consolidated Adjusted EBITDA of $63.8 million.

The company maintained robust drilling activity with 88 active rigs representing 17% market share of U.S. land rigs. Kimbell's major properties had 7.99 net DUCs and permitted locations, exceeding the 6.5 net wells needed for flat production. The company will utilize 25% of available cash to repay approximately $13.6 million of outstanding credit facility borrowings.

Positive

• None.

Negative

• Overall U.S. land rig count dropped 7% quarter-over-quarter
• Significant debt level with $462.1M outstanding under revolving credit facility
• Decreased realized commodity prices with oil at $63.48/Bbl and natural gas at $2.54/Mcf
• Mid-Con region experienced decline in drilling activity

Insights

Oil & Gas Royalty Financial Analyst

Kimbell's Q2 shows steady performance with 10.3% yield distribution and favorable drilling activity despite industry slowdown.

Kimbell Royalty Partners delivered stable Q2 2025 results with production of 25,355 Boe/d and revenue of $74.7 million. The company's consolidated Adjusted EBITDA reached $63.8 million, while maintaining impressively low Cash G&A of $2.36 per BOE, beating their own guidance.

The royalty business model is displaying its defensive characteristics amidst a challenging drilling environment. While the overall U.S. land rig count dropped 7% quarter-over-quarter, Kimbell's rig count only decreased by 2% to 88 active rigs. This gives them a remarkable 17% market share of all U.S. land drilling activity - actually increasing by 1% from the previous quarter. The relative outperformance in rig retention demonstrates the high-quality nature of Kimbell's acreage positions.

Their inventory of drilled but uncompleted wells (DUCs) increased 9% quarter-over-quarter, particularly in the Permian Basin, which signals continued production momentum in coming quarters. With 7.99 net DUCs and permitted locations versus only 6.5 net wells needed for flat production, they have ample visibility into maintaining output levels.

The company declared a quarterly distribution of $0.38 per unit, representing a 10.3% annualized yield based on their current price. Importantly, approximately 100% of this distribution is expected to be tax-advantaged as return of capital rather than dividend income. The company is maintaining financial discipline by allocating 25% of distributable cash flow to debt reduction, with $13.6 million earmarked to pay down their credit facility.

With a net debt to trailing twelve-month Adjusted EBITDA ratio of 1.6x, Kimbell maintains a conservative balance sheet. Their recent credit facility redetermination increased their borrowing base from $550 million to $625 million, indicating lenders' confidence in their asset quality. The redemption of 50% of preferred units further simplifies their capital structure and reduces capital costs.

The company has positioned itself defensively with an active hedging program extending through Q2 2027, providing cash flow stability in volatile commodity markets, with current hedges at favorable prices relative to spot markets, particularly for natural gas.

Q2 2025 Run-Rate Daily Production of 25,355 Boe/d (6:1)

Activity on Acreage Remains Robust with 88 Active Rigs Drilling Representing 17%¹ Market Share of U.S. Land Rig Count

Announces Q2 2025 Cash Distribution of $0.38 per Common Unit

FORT WORTH, Texas, Aug. 7, 2025 /PRNewswire/ -- Kimbell Royalty Partners, LP (NYSE: KRP) ("Kimbell" or the "Company"), a leading owner of oil and natural gas mineral and royalty interests in over 131,000 gross wells across 28 states, today announced financial and operating results for the quarter ended June 30, 2025. 

Second Quarter 2025 Highlights

• Q2 2025 run-rate daily production of 25,355 barrels of oil equivalent ("Boe") per day (6:1)
• Q2 2025 oil, natural gas and NGL revenues of $74.7 million
• Q2 2025 net income of approximately $26.7 million and net income attributable to common units of approximately $2.0 million
• Q2 2025 consolidated Adjusted EBITDA of $63.8 million
• Cash G&A per BOE of $2.36 in Q2 2025, below low-end of guidance reflecting operational discipline and positive operating leverage
• As of June 30, 2025, Kimbell's major properties² had 7.99 net DUCs and net permitted locations on its acreage (5.10 net DUCs and 2.89 net permitted locations) compared to an estimated 6.5 net wells needed to maintain flat production
• As of June 30, 2025, Kimbell had 88 rigs actively drilling on its acreage, representing approximately 17% market share of all land rigs drilling in the continental United States as of such time
• Announced a Q2 2025 cash distribution of $0.38 per common unit, reflecting a payout ratio of 75% of cash available for distribution; implies a 10.3% annualized yield based on the August 6, 2025 closing price of $14.79 per common unit; Kimbell intends to utilize the remaining 25% of its cash available for distribution to repay a portion of the outstanding borrowings under Kimbell's secured revolving credit facility
• Kimbell affirms its financial and operational guidance ranges for 2025 previously disclosed in its Q4 2024 earnings release

Robert Ravnaas, Chairman and Chief Executive Officer of Kimbell Royalty GP, LLC, Kimbell's general partner (the "General Partner"), commented, "Kimbell's active rig count remains strong with our market share of U.S. land rigs actively drilling increasing by 1% to 17%.  In addition, while the overall U.S. land rig count dropped by 7% quarter over quarter as operators, primarily in the Permian, slowed drilling activity, our overall rig count dropped by only 2% to 88 rigs actively drilling on our acreage.  Notably, our rig count in the Permian Basin increased by four rigs and Haynesville increased by five rigs while the Mid-Con experienced a decline in drilling activity.  Furthermore, our line-of-site wells continue to be well above the number of wells needed to maintain flat production, giving us confidence in the resilience of our production as we progress through 2025.  More specifically, net DUCs increased by 9% quarter over quarter, led by the Permian Basin, which bodes well for near-term production contributions from this region.  Finally, cash G&A per BOE was well below the low end of guidance reflecting operational discipline and positive operating leverage.

"We are pleased to declare the Q2 2025 distribution of 38 cents per common unit, reflecting a 10.3% annualized tax advantaged yield based on Kimbell's closing price on August 6, 2025.  We estimate that approximately 100% of this distribution is expected to be considered return of capital and not subject to dividend taxes, further enhancing the after-tax return to our common unitholders."

___________________________

1 Based on Kimbell rig count of 88 and Baker Hughes U.S. land rig count of 533 as of June 30, 2025.

2 These figures pertain only to Kimbell's major properties and do not include possible additional DUCs and permits from Kimbell's minor properties, which generally have a net revenue interest of 0.1% or below and are time consuming to quantify but, in the estimation of Kimbell's management, could add an additional 15% to Kimbell's net inventory.

Second Quarter 2025 Distribution and Debt Repayment

Today, the Board of Directors of the General Partner (the "Board of Directors") approved a cash distribution payment to common unitholders of 75% of cash available for distribution for the second quarter of 2025, or $0.38 per common unit.  The distribution will be payable on August 25, 2025 to common unitholders of record at the close of business on August 18, 2025.  Kimbell plans to utilize the remaining 25% of cash available for distribution for the second quarter of 2025 to pay down approximately $13.6 million of the outstanding borrowings under its secured revolving credit facility. 

Kimbell expects that approximately 100% of its second quarter 2025 distribution should not constitute dividends for U.S. federal income tax purposes, but instead are estimated to constitute non-taxable reductions to the basis of each distribution recipient's ownership interest in Kimbell common units.  The reduced tax basis will increase unitholders' capital gain (or decrease unitholders' capital loss) when unitholders sell their common units.  The Form 8937 containing additional information may be found at www.kimbellrp.com under "Investor Relations" section of the site.  Kimbell currently believes that the portion that constitutes dividends for U.S. federal income tax purposes will be considered qualified dividends, subject to holding period and certain other conditions, which are subject to a tax rate of 0%, 15% or 20% depending on the income level and tax filing status of a unitholder for 2025.  Kimbell believes these estimates are reasonable based on currently available information, but they are subject to change.

Financial Highlights

Kimbell's second quarter 2025 average realized price per Bbl of oil was $63.48, per Mcf of natural gas was $2.54, per Bbl of NGLs was $24.10 and per Boe combined was $33.04.

During the second quarter of 2025, the Company's total revenues were $86.5 million, net income was approximately $26.7 million and net income attributable to common units was approximately $2.0 million, or $0.02 per common unit.

Total second quarter 2025 consolidated Adjusted EBITDA was $63.8 million (consolidated Adjusted EBITDA is a non-GAAP financial measure. Please see a reconciliation to the nearest GAAP financial measures at the end of this news release). 

In the second quarter of 2025, G&A expense was $9.6 million, $5.4 million of which was Cash G&A expense, or $2.36 per BOE (Cash G&A and Cash G&A per Boe are non-GAAP financial measures.  Please see definition under Non-GAAP Financial Measures in the Supplemental Schedules included in this news release).  Unit-based compensation in the second quarter of 2025, which is a non-cash G&A expense, was $4.1 million or $1.79 per Boe.

As of June 30, 2025, Kimbell had approximately $462.1 million in debt outstanding under its secured revolving credit facility, had net debt to second quarter 2025 trailing twelve month consolidated Adjusted EBITDA of approximately 1.6x and was in compliance with all financial covenants under its secured revolving credit facility.  Kimbell had approximately $162.9 million in undrawn capacity under its secured revolving credit facility as of June 30, 2025.

On May 1, 2025, the borrowing base and aggregate commitments on Kimbell's secured revolving credit facility were increased from $550 million to $625 million in connection with its spring redetermination.  In addition, on May 7, 2025, the Company redeemed 50% of its Series A Cumulative Convertible Preferred Units outstanding, further simplifying its capital structure and reducing its cost of capital.

As of June 30, 2025, Kimbell had outstanding 93,396,488 common units and 14,491,540 Class B units.  As of August 7, 2025, Kimbell had outstanding 93,396,488 common units and 14,491,540 Class B units.

Production

Second quarter 2025 run-rate average daily production was 25,355 Boe per day (6:1), which was composed of approximately 47% from natural gas (6:1) and approximately 53% from liquids (33% from oil and 20% from NGLs).

Operational Update

As of June 30, 2025, Kimbell's major properties had 823 gross (5.10 net) DUCs and 687 gross (2.89 net) permitted locations on its acreage.  In addition, as of June 30, 2025, Kimbell had 88 rigs actively drilling on its acreage, which represents an approximate 16.5% market share of all land rigs drilling in the continental United States as of such time.

Basin	Gross DUCs as of June 30, 2025(1)	Gross Permits as of June 30, 2025(1)	Net DUCs as of June 30, 2025(1)	Net Permits as of June 30, 2025(1)
Permian	524	459	3.27	2.15
Eagle Ford	55	15	0.22	0.08
Haynesville	54	30	0.35	0.13
Mid-Continent	114	76	0.78	0.39
Bakken	61	97	0.36	0.10
Appalachia	3	4	0.02	0.02
Rockies	12	6	0.10	0.02
Total	823	687	5.10	2.89

_______________________________________________________________________________

(1)  These figures pertain only to Kimbell's major properties and do not include possible additional DUCs and permits from Kimbell's minor properties, which generally have a net revenue interest of 0.1% or below and are time consuming to quantify but, in the estimation of Kimbell's management, could add an additional 15% to Kimbell's net inventory.

Hedging Update

The following provides information concerning Kimbell's hedge book as of June 30, 2025:

Fixed Price Swaps as of June 30, 2025
			Weighted Average
	Volumes		Fixed Price
	Oil	Nat Gas	Oil	Nat Gas
	BBL	MMBTU	$/BBL	$/MMBTU
3Q 2025	136,068	1,261,964	$        74.20	$          3.74
4Q 2025	146,372	1,291,680	$        68.26	$          3.68
1Q 2026	146,880	1,296,000	$        70.38	$          4.07
2Q 2026	148,512	1,310,400	$        70.78	$          3.33
3Q 2026	150,144	1,324,800	$        66.60	$          3.42
4Q 2026	150,144	1,324,800	$        63.33	$          3.94
1Q 2027	151,470	1,321,920	$        63.75	$          4.46
2Q 2027	153,153	1,336,608	$        61.57	$          3.47

Conference Call

Kimbell Royalty Partners will host a conference call and webcast today at 10:00 a.m. Central Time (11:00 a.m. Eastern Time) to discuss second quarter 2025 results.  To access the call live by phone, dial 201-389-0869 and ask for the Kimbell Royalty Partners call at least 10 minutes prior to the start time.  A telephonic replay will be available through August 14, 2025 by dialing 201-612-7415 and using the conference ID 13752278#.  A webcast of the call will also be available live and for later replay on Kimbell's website at http://kimbellrp.investorroom.com under the Events and Presentations tab. 

Presentation

On August 7, 2025, Kimbell posted an updated investor presentation on its website.  The presentation may be found at http://kimbellrp.investorroom.com under the Events and Presentations tab.  Information on Kimbell's website does not constitute a portion of this news release.

About Kimbell Royalty Partners, LP

Kimbell (NYSE: KRP) is a leading oil and gas mineral and royalty company based in Fort Worth, Texas.  Kimbell owns mineral and royalty interests in over 17 million gross acres in 28 states and in every major onshore basin in the continental United States, including ownership in more than 131,000 gross wells.  To learn more, visit http://www.kimbellrp.com.

Forward-Looking Statements

This news release includes forward-looking statements, in particular statements relating to Kimbell's financial, operating and production results and prospects for growth (including financial and operational guidance), drilling inventory, growth potential, identified locations and all other estimates and predictions resulting from Kimbell's portfolio review, the tax treatment of Kimbell's distributions, changes in Kimbell's capital structure, future natural gas and other commodity prices and changes to supply and demand for oil, natural gas and NGLs. These and other forward-looking statements involve risks and uncertainties, including risks that the anticipated benefits of acquisitions are not realized and uncertainties relating to Kimbell's business, prospects for growth and acquisitions and the securities markets generally, as well as risks inherent in oil and natural gas drilling and production activities, including risks with respect to potential declines in prices for oil and natural gas that could result in downward revisions to the value of proved reserves or otherwise cause operators to delay or suspend planned drilling and completion operations or reduce production levels, which would adversely impact cash flow, risks relating to the impairment of oil and natural gas properties, risk related to changes in U.S. trade policy and the impact of tariffs, risks relating to the availability of capital to fund drilling operations that can be adversely affected by adverse drilling results, production declines and declines in oil and natural gas prices, risks relating to Kimbell's ability to meet financial covenants under its credit agreement or its ability to obtain amendments or waivers to effect such compliance, risks relating to Kimbell's hedging activities, risks of fire, explosion, blowouts, pipe failure, casing collapse, unusual or unexpected formation pressures, environmental hazards, and other operating and production risks, which may temporarily or permanently reduce production or cause initial production or test results to not be indicative of future well performance or delay the timing of sales or completion of drilling operations, risks relating to delays in receipt of drilling permits, risks relating to unexpected adverse developments in the status of properties, risks relating to borrowing base redeterminations by Kimbell's lenders, risks relating to the absence or delay in receipt of government approvals or third-party consents, risks relating to acquisitions, dispositions and drop downs of assets, risks relating to Kimbell's ability to realize the anticipated benefits from and to integrate acquired assets, including the Acquired Production, risks relating to tax matters and other risks described in Kimbell's Annual Report on Form 10-K and other filings with the Securities and Exchange Commission (the "SEC"), available at the SEC's website at www.sec.gov. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of this news release. Except as required by law, Kimbell undertakes no obligation and does not intend to update these forward-looking statements to reflect events or circumstances occurring after this news release. When considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements in Kimbell's filings with the SEC.

Contact:

Rick Black
Dennard Lascar Investor Relations
krp@dennardlascar.com
(713) 529-6600

– Financial statements follow –

 

Kimbell Royalty Partners, LP Condensed Consolidated Balance Sheet (Unaudited, in thousands)
	June 30,
	2025
Assets:
Current assets
Cash and cash equivalents	$	34,524
Oil, natural gas and NGL receivables		47,989
Derivative assets		3,773
Accounts receivable and other current assets		1,963
Total current assets		88,249
Property and equipment, net		557
Oil and natural gas properties
Oil and natural gas properties (full cost method)		2,271,464
Less: accumulated depreciation, depletion and impairment		(1,085,279)
Total oil and natural gas properties, net		1,186,185
Right-of-use assets, net		4,783
Derivative assets		267
Loan origination costs, net		4,895
Total assets	$	1,284,936
Liabilities, mezzanine equity and unitholders' equity:
Current liabilities
Accounts payable	$	3,093
Other current liabilities		13,092
Total current liabilities		16,185
Operating lease liabilities, excluding current portion		4,573
Derivative liabilities		669
Long-term debt		462,096
Other liabilities		10
Total liabilities		483,533
Commitments and contingencies
Mezzanine equity:
Series A preferred units		158,395
Kimbell Royalty Partners, LP unitholders' equity:
Common units		555,914
Class B units		724
Total Kimbell Royalty Partners, LP unitholders' equity		556,638
Non-controlling interest in OpCo		86,370
Total unitholders' equity		643,008
Total liabilities, mezzanine equity and unitholders' equity	$	1,284,936

 

Kimbell Royalty Partners, LP Condensed Consolidated Statements of Operations (Unaudited, in thousands, except per-unit data and unit counts)
	Three Months Ended			Three Months Ended
	June 30, 2025			June 30, 2024
Revenue
Oil, natural gas and NGL revenues	$	74,695		$	76,959
Lease bonus and other income		2,514			660
Gain (loss) on commodity derivative instruments, net		9,339			(1,046)
Total revenues		86,548			76,573
Costs and expenses
Production and ad valorem taxes		5,715			5,577
Depreciation and depletion expense		30,458			33,024
Marketing and other deductions		3,016			3,828
General and administrative expense		9,573			10,252
Total costs and expenses		48,762			52,681
Operating income		37,786			23,892
Other expense
Interest expense		(8,947)			(6,946)
Net income before income taxes		28,839			16,946
Income tax expense		2,167			1,759
Net income		26,672			15,187
Distribution and accretion on Series A preferred units		(24,337)			(5,243)
Net income attributable to non-controlling interests		(314)			(1,513)
Distributions to Class B unitholders		(14)			(21)
Net income attributable to common units of Kimbell Royalty Partners, LP	$	2,007		$	8,410
Basic	$	0.02		$	0.11
Diluted	$	0.02		$	0.11
Weighted average number of common units outstanding
Basic		91,170,092			74,834,777
Diluted		122,924,241			116,593,560

Kimbell Royalty Partners, LP
Supplemental Schedules

NON-GAAP FINANCIAL MEASURES

Adjusted EBITDA, Cash G&A and Cash G&A per Boe are used as supplemental non-GAAP financial measures by management and external users of Kimbell's financial statements, such as industry analysts, investors, lenders and rating agencies.  Kimbell believes Adjusted EBITDA is useful because it allows us to more effectively evaluate Kimbell's operating performance and compare the results of Kimbell's operations period to period without regard to its financing methods or capital structure.  In addition, management uses Adjusted EBITDA to evaluate cash flow available to pay distributions to Kimbell's unitholders.  Kimbell defines Adjusted EBITDA as net income (loss), net of depreciation and depletion expense, interest expense, income taxes, impairment of oil and natural gas properties, non-cash unit-based compensation and unrealized gains and losses on derivative instruments.  Adjusted EBITDA is not a measure of net income (loss) or net cash provided by operating activities as determined by GAAP.  Kimbell excludes the items listed above from net income (loss) in arriving at Adjusted EBITDA because these amounts can vary substantially from company to company within Kimbell's industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired.  Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company's financial performance, such as a company's cost of capital and tax structure, as well as historic costs of depreciable assets, none of which are components of Adjusted EBITDA.  Adjusted EBITDA should not be considered an alternative to net income, oil, natural gas and natural gas liquids revenues, net cash provided by operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP.  Kimbell's computations of Adjusted EBITDA may not be comparable to other similarly titled measures of other companies.  Kimbell expects that cash available for distribution for each quarter will generally equal its Adjusted EBITDA for the quarter, less cash needed for debt service and other contractual obligations, tax obligations, and fixed charges and reserves for future operating or capital needs that the Board of Directors may determine is appropriate.

Kimbell believes Cash G&A and Cash G&A per Boe are useful metrics because they isolate cash costs within overall G&A expense and measure cash costs relative to overall production, which is a widely utilized metric to evaluate operational performance within the energy sector.  Cash G&A is defined as general and administrative expenses less unit-based compensation expense.  Cash G&A per Boe is defined as Cash G&A divided by total production for a period.  Cash G&A should not be considered an alternative to G&A expense presented in accordance with GAAP. Kimbell's computations of Cash G&A and Cash G&A per Boe may not be comparable to other similarly titled measures of other companies.

 

Kimbell Royalty Partners, LP Supplemental Schedules (Unaudited, in thousands)
	Three Months Ended			Three Months Ended
	June 30, 2025			June 30, 2024
Reconciliation of net cash provided by operating activities
to Adjusted EBITDA and cash available for distribution
Net cash provided by operating activities	$	72,321		$	62,883
Interest expense		8,947			6,946
Income tax expense		2,167			1,759
Amortization of right-of-use assets		(86)			(87)
Amortization of loan origination costs		(579)			(530)
Unit-based compensation		(4,124)			(5,109)
Gain (loss) on derivative instruments, net of settlements		8,524			(3,796)
Changes in operating assets and liabilities:
Oil, natural gas and NGL revenues receivable		(13,009)			(1,486)
Accounts receivable and other current assets		(792)			(460)
Accounts payable		3			353
Other current liabilities		(5,208)			(3,651)
Operating lease liabilities		80			94
Consolidated EBITDA	$	68,244		$	56,916
Add:
Unit-based compensation		4,124			5,109
(Gain) loss on derivative instruments, net of settlements		(8,524)			3,796
Consolidated Adjusted EBITDA	$	63,844		$	65,821
Adjusted EBITDA attributable to non-controlling interest		(8,576)			(10,011)
Adjusted EBITDA attributable to Kimbell Royalty Partners, LP	$	55,268		$	55,810
Adjustments to reconcile Adjusted EBITDA to cash available
for distribution
Less:
Cash interest expense		5,810			5,620
Cash distribution to Series A preferred unitholders		2,104			4,111
Cash income tax expense		219			—
Distribution to Class B unitholders		14			21
Cash available for distribution on common units	$	47,121		$	46,058

 

Kimbell Royalty Partners, LP Supplemental Schedules (Unaudited, in thousands, except for per-unit data and unit counts)
	Three Months Ended
	June 30, 2025
Net income	$	26,672
Depreciation and depletion expense		30,458
Interest expense		8,947
Income tax expense		2,167
Consolidated EBITDA	$	68,244
Unit-based compensation		4,124
Gain on derivative instruments, net of settlements		(8,524)
Consolidated Adjusted EBITDA	$	63,844
Adjusted EBITDA attributable to non-controlling interest		(8,576)
Adjusted EBITDA attributable to Kimbell Royalty Partners, LP	$	55,268
Adjustments to reconcile Adjusted EBITDA to cash available
for distribution
Less:
Cash interest expense		5,810
Cash distribution to Series A preferred unitholders		2,104
Cash income tax expense		219
Distribution to Class B unitholders		14
Cash available for distribution on common units	$	47,121
Common units outstanding on June 30, 2025		93,396,488
Common units outstanding on August 18, 2025 Record Date		93,396,488
Cash available for distribution per common unit outstanding	$	0.50
Second quarter 2025 distribution declared (1)	$	0.38

(1)  The difference between the declared distribution and the cash available for distribution is primarily attributable to Kimbell allocating 25% of cash available for distribution to pay outstanding borrowings under its secured revolving credit facility.

 

Kimbell Royalty Partners, LP Supplemental Schedules (Unaudited, in thousands, except for per-unit data and unit counts)
	Three Months Ended
	June 30, 2024
Net income	$	15,187
Depreciation and depletion expense		33,024
Interest expense		6,946
Income tax expense		1,759
Consolidated EBITDA	$	56,916
Unit-based compensation		5,109
Loss on derivative instruments, net of settlements		3,796
Consolidated Adjusted EBITDA	$	65,821
Adjusted EBITDA attributable to non-controlling interest		(10,011)
Adjusted EBITDA attributable to Kimbell Royalty Partners, LP	$	55,810
Adjustments to reconcile Adjusted EBITDA to cash available
for distribution
Less:
Cash interest expense		5,620
Cash distribution to Series A preferred unitholders		4,111
Distribution to Class B unitholders		21
Cash available for distribution on common units	$	46,058
Common units outstanding on June 30, 2024		80,969,651
Common units outstanding on August 12, 2024 Record Date		80,969,651
Cash available for distribution per common unit outstanding	$	0.57
Second quarter 2024 distribution declared (1)	$	0.42

(1)  The difference between the declared distribution and the cash available for distribution is primarily attributable to Kimbell allocating 25% of cash available for distribution to pay outstanding borrowings under its secured revolving credit facility.

 

Kimbell Royalty Partners, LP Supplemental Schedules (Unaudited, in thousands)
	Three Months Ended
	June 30, 2025
Net income	$	26,672
Depreciation and depletion expense		30,458
Interest expense		8,947
Income tax expense		2,167
Consolidated EBITDA	$	68,244
Unit-based compensation		4,124
Gain on derivative instruments, net of settlements		(8,524)
Consolidated Adjusted EBITDA	$	63,844
Q3 2024 - Q1 2025 Consolidated Adjusted EBITDA (1)		215,972
Trailing Twelve Month Consolidated Adjusted EBITDA	$	279,816
Long-term debt (as of 6/30/25)		462,096
Cash and cash equivalents (as of 6/30/25) (2)		(25,000)
Net debt (as of 6/30/25)	$	437,096
Net Debt to Trailing Twelve Month Consolidated Adjusted EBITDA		1.6x

(1)  Consolidated Adjusted EBITDA for each of the quarters ended September 30, 2024, December 31, 2024 and March 31, 2025 was previously reported in a news release relating to the applicable quarter, and the reconciliation of net income to consolidated Adjusted EBITDA for each quarter is included in the applicable news release.  This also includes the trailing twelve months pro forma results from the Q1 2025 acquisition that closed in January 2025 in accordance with Kimbell's secured revolving credit facility.

(2)  In accordance with Kimbell's secured revolving credit facility, the maximum deduction of cash and cash equivalents to be included in the net debt calculation for compliance purposes is $25 million.

   

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SOURCE Kimbell Royalty Partners, LP

FAQ

What were Kimbell Royalty Partners' (KRP) key financial results for Q2 2025?

KRP reported Q2 2025 revenues of $74.7 million, net income of $26.7 million, and consolidated Adjusted EBITDA of $63.8 million.

What is KRP's Q2 2025 distribution amount and yield?

KRP announced a $0.38 per common unit distribution, representing a 10.3% annualized yield based on the August 6, 2025 closing price.

How many active drilling rigs does Kimbell Royalty Partners have on its acreage in Q2 2025?

KRP had 88 active rigs drilling on its acreage, representing approximately 17% market share of all U.S. land rigs.

What is Kimbell Royalty Partners' current production level?

KRP's Q2 2025 run-rate daily production was 25,355 Boe per day, composed of 47% natural gas and 53% liquids.

What is KRP's debt position as of Q2 2025?

KRP had $462.1 million in debt outstanding under its secured revolving credit facility, with a net debt to trailing twelve-month Adjusted EBITDA ratio of 1.6x.

How is Kimbell Royalty Partners managing its cash distribution?

KRP is distributing 75% of available cash to unitholders and using the remaining 25% to repay approximately $13.6 million of credit facility debt.