FORT WORTH, Texas, Aug. 6, 2020 /PRNewswire/ -- Kimbell Royalty Partners, LP (NYSE: KRP) ("Kimbell" or the "Company"), a leading owner of oil and natural gas mineral and royalty interests in more than 96,000 gross wells across 28 states, today announced financial and operating results for the second quarter ended June 30, 2020. 

Second Quarter 2020 Highlights

• Q2 2020 run-rate daily production of 14,069 barrels of oil equivalent ("Boe") per day (6:1)
• Including a full quarter of the production attributable to the Springbok assets, Q2 2020 run-rate daily production of 14,090 Boe per day (6:1), down 7% from Q1 2020 record production of 15,188 Boe per day (6:1)
• Substantially all of the decrease in production between Q1 2020 and Q2 2020 was due to curtailments that occurred in Q2 2020
• Q2 2020 production was comprised of approximately 41% from liquids (28% from oil and 13% from natural gas liquids ("NGL")) and approximately 59% from natural gas (6:1)
• Q2 2020 oil, natural gas and NGL revenues of $16.8 million, reflecting impacts from the COVID-19 pandemic and related supply/demand imbalances in the U.S. oil and natural gas markets that significantly depressed production prices
• Q2 2020 realized hedging gains of $2.9 million; substantial portion of projected oil and natural gas production hedged through Q2 2022
• Q2 2020 net loss of $76.8 million and Q2 2020 net loss attributable to common units of $48.0 million. The Q2 2020 net loss amount was primarily due to a non-cash ceiling test impairment expense of $65.5 million related to the substantial weakness in commodity prices
• Q2 2020 consolidated Adjusted EBITDA of $12.1 million
• As of June 30, 2020, Kimbell had 806 gross (2.98 net) drilled but uncompleted wells ("DUCs") and 611 gross (2.25 net) permitted locations on its acreage
• As of June 30, 2020, Kimbell had 29 rigs actively drilling on our acreage, which represented 11.6%¹ market share of all rigs drilling in the continental United States as of such time
• Announced a cash distribution of $0.13 per common unit and an increase in the pay-out ratio of cash available for distribution from 50% in Q1 2020 to 75% in Q2 2020; implies a 5.8% annualized yield based on the August 5, 2020 closing price of $9.00 per common unit; Kimbell intends to utilize the remaining 25% of its available cash to repay a portion of the outstanding borrowings under Kimbell's credit facility
• On June 1, 2020, Kimbell received unanimous reaffirmation of its $300.0 million borrowing base and total commitments of $225.0 million

Robert Ravnaas, Chairman and Chief Executive Officer of Kimbell's general partner commented, "We are encouraged by what we see as a gradual recovery in both commodity prices and the U.S. economy and are cautiously optimistic that the worst is behind us with regard to production curtailments.  Despite challenges during the second quarter, we believe we benefited from the full integration of the Springbok assets and increased our Q2 2020 payout ratio from 50% to 75% of cash available for distribution.  We believe the Kimbell business model is highly differentiated from most companies in the U.S. energy sector given our pure royalty model, diverse asset base, mix of commodities, substantial hedges and low PDP decline rate, which is among the best in the industry.  While many risks and uncertainties remain in the economy and surrounding the continuing COVID-19 crisis, we believe Kimbell is well-positioned to manage its business through these challenges."

Second Quarter 2020 Distribution and Debt Repayment

On July 24, 2020, the Board of Directors of Kimbell Royalty GP, LLC, Kimbell's 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 2020, or $0.13 per common unit.  The cash distribution will be payable on August 10, 2020 to common unitholders of record at the close of business on August 3, 2020.  The Board of Directors will review the distribution policy quarterly.  Kimbell expects to utilize the remaining 25% of cash available for distribution for the second quarter of 2020 to pay-down $2.5 million of outstanding borrowings under Kimbell's credit facility. 

Kimbell expects that substantially all of its second quarter distribution will not constitute taxable dividend income and instead will generally result in a non-taxable reduction to the tax basis of unitholders' common units.  The reduced tax basis will increase unitholders' capital gain (or decrease unitholders' capital loss) when unitholders sell their common units.  Furthermore, Kimbell expects that substantially all distributions paid to common unitholders from 2020 through 2023 will not be taxable dividend income and less than 25% of distributions paid to common unitholders for the subsequent two years (2024 to 2025) will be taxable dividend income. 

Financial Highlights

Kimbell's second quarter 2020 average realized price per Bbl of oil was $24.89, per Mcf of natural gas was $1.44, per Bbl of NGLs was $7.87 and per Boe combined was $13.09.

During the second quarter of 2020, the Company's total revenues were $12.8 million, net loss was $76.8 million and net loss attributable to common units was $48.0 million, or $1.39 per common unit.  The net loss during the second quarter of 2020 was primarily due to a $65.5 million non-cash ceiling test impairment expense recorded during the quarter related to the substantial weakness in commodity prices.  This non-cash ceiling test impairment is not expected to impact the cash flow available for distribution generated by Kimbell or its liquidity or ability to make acquisitions in the future.

Total second quarter 2020 consolidated Adjusted EBITDA was $12.1 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).  Our second quarter 2020 consolidated Adjusted EBITDA was reduced by a one-time $300,000 expense related to the transition services agreement entered into in connection with our acquisition of the Springbok assets.

G&A expense was $6.9 million in Q2 2020, $4.3 million of which was Cash G&A expense, or $3.48 per Boe (Cash G&A and Cash G&A per Boe are non-GAAP financial measures.  Please see definition under Non-GAAP Financial Measures at end of this news release).  Unit-based compensation in Q2 2020, which is a non-cash G&A expense, was $2.5 million or $2.04 per Boe.  Cash G&A expense per Boe was increased by a one-time $300,000 expense related to the transition services agreement entered into in connection with our acquisition of the Springbok assets.

Although there has been stabilization in the oil and natural gas markets since the second quarter, Kimbell believes that the ongoing COVID-19 outbreak and potential supply/demand imbalances in the oil and natural gas markets could continue to have an adverse effect on Kimbell's business, production, cash flows, financial condition and results of operations in the second half of 2020.

At June 30, 2020, Kimbell had approximately $171.7 million in debt outstanding under its revolving credit facility, total debt to Q2 2020 trailing twelve month consolidated Adjusted EBITDA of approximately 2.3x and was in compliance with all financial covenants under its revolving credit facility. 

After giving effect to $477,051 in borrowings to fund acquisitions under Kimbell's micro investment strategy so far in Q3 2020 and the repayment of $2.5 million in outstanding borrowings discussed above, which is anticipated to occur in Q3 2020, Kimbell expects to have approximately $169.7 million in outstanding borrowings under its revolving credit facility and approximately $55.3 million in undrawn capacity (or approximately $130.3 million if aggregate commitments were equal to Kimbell's current borrowing base, which is $300.0 million).  Increases in commitments pursuant to the accordion feature of the revolving credit facility are subject to the satisfaction of certain conditions, including obtaining additional commitments from new or existing lenders. 

Production

Second quarter 2020 average daily production was 14,254 Boe per day (6:1), which consisted of 185 Boe per day relating to prior period production recognized in Q2 2020 and 14,069 Boe per day of run-rate production.  The 14,069 Boe per day of run-rate production for Q2 2020 was comprised of approximately 41% from liquids (28% from oil and 13% from NGLs) and approximately 59% from natural gas (6:1).  The prior period production recognized in Q2 2020 was primarily due to new wells outperforming estimates.

Operational Update

As of June 30, 2020, Kimbell had 806 gross (2.98 net) DUCs and 611 gross (2.25 net) permitted locations on its acreage.  In addition, as of June 30, 2020, Kimbell had 29 rigs actively drilling on its acreage, which represents an approximate 11.6% market share of all land rigs drilling in the continental United States as of such time.

Hedging Update

The following provides information concerning Kimbell's hedge book as of June 30, 2020:

Conference Call

Kimbell Royalty Partners will host a conference call and webcast today at 11:00 a.m. Eastern Time (10:00 a.m. Central Time) to discuss second quarter 2020 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 13, 2020, by dialing 201-612-7415 and using the conference ID 13704472#.  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 6, 2020, 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 13 million gross acres in 28 states and in every major onshore basin in the continental United States, including ownership in more than 96,000 gross wells with over 40,000 wells in the Permian Basin.  To learn more, visit http://www.kimbellrp.com.

Forward-Looking Statements

This news release includes forward-looking statements, in particular statements relating to the acquisition of the Springbok assets, Kimbell's financial, operating and production results and prospects for growth, the tax treatment of Kimbell's distributions and the recent COVID-19 outbreak and its impacts on Kimbell and on the oil and gas industry. These and other forward-looking statements involve risks and uncertainties, including risks that the anticipated benefits of the acquisition of the Springbok assets are not realized, risks relating to Kimbell's integration of the Springbok assets, risks relating to the COVID-19 outbreak, 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 low or declining 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 related to the impact of COVID-19 on the global economy and Kimbell's business, risks relating to the impairment of oil and natural gas properties, 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 Springbok assets, 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
Supplemental Schedules

NON-GAAP FINANCIAL MEASURES

Adjusted EBITDA and Cash G&A are used as a 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) before interest expense, non-cash unit-based compensation, unrealized gains and losses on commodity derivative instruments, equity income from affiliates, impairment of oil and natural gas properties, income taxes and depreciation and depletion expense, and adjusted for distributions from equity investments.  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 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.

SOURCE Kimbell Royalty Partners, LP