FORT WORTH, Texas, Aug. 8, 2019 /PRNewswire/ -- Kimbell Royalty Partners, LP (NYSE: KRP) ("Kimbell Royalty Partners" or "Kimbell"), a leading owner of oil and natural gas mineral and royalty interests in more than 92,000 gross producing wells across 28 states, today announced financial and operating results for the second quarter ended June 30, 2019. 

Second Quarter 2019 Highlights

• Q2 2019 cash distribution of $0.39 per common unit, up 5.4% from Q1 2019; implies a robust 11.3% annualized yield based on the August 6, 2019 closing price of $13.84 per common unit
• Kimbell expects that substantially all of the Q1 2019 and Q2 2019 distributions to common unitholders will not constitute taxable dividend income and instead will generally result in non-taxable reductions to the tax basis of unitholders' common units
• Q2 2019 record oil, natural gas and natural gas liquids ("NGL") revenues of $27.9 million, up 22% from Q1 2019, primarily attributable to a full quarter of revenue from the Phillips assets
• Q2 2019 average daily production of 11,807 barrels of oil equivalent ("Boe") per day, up 225% from Q2 2018
• Q2 2019 oil price realizations increased 13.1%, natural gas price realizations decreased 9.0%, NGL price realizations decreased 0.8% and combined price realizations increased 2.7% compared to Q1 2019, excluding the impact of hedging
• Q2 2019 net loss was $20.4 million and net loss attributable to common units was $11.8 million compared to net income attributable to common units of $1.4 million in Q2 2018, due to a $28.1 million non-cash impairment in Q2 2019
• Q2 2019 record consolidated Adjusted EBITDA (as defined and reconciled below) of $21.6 million, up 33.9% from Q1 2019
• Committed up to $15 million of total capital commitments to a newly formed joint venture, implementing a "ground-game" strategy to aggregate minerals in the micro-market across multiple resource plays
• Kimbell reaffirms guidance

Robert Ravnaas, Chairman and Chief Executive Officer of Kimbell Royalty Partners' general partner commented, "After closing approximately $700 million in acquisitions over the last twelve months, we completed the integration of the Phillips assets, which we recently acquired from EnCap, in the second quarter.  We are very pleased with the cash flow generation, production stability and growth potential across our asset base, especially in a challenging time for many exploration and production companies operating in the U.S.  Our rig count remained flat between Q1 and Q2 2019 at 89 rigs and our market share of the entire lower 48 drilling fleet increased to 9.5% from 9.1%, a testament to the quality of our acreage and operators.  In addition, revenue growth in the quarter reflected a full quarter of our Phillips assets, improved differentials and the receipt of over $1 million in lease bonuses.  With our most recent distribution of 39 cents per common unit, Kimbell is now paying a 11.3% annualized yield, which we expect will not be subject to dividend income taxes and instead expect to be considered a return of capital. 

"We continue to actively evaluate a number of acquisition opportunities across our many basins.  We remain focused on assembling a high-quality, low PDP decline and diversified royalty portfolio that generates substantial cash flow and growth potential with no additional capital outlays.  We will remain patient and highly selective on seeking the best acquisition opportunities that are not only immediately accretive to our unitholders, but also enhance the long-term value of our overall portfolio," concluded Robert Ravnaas.

Second Quarter 2019 Distribution

On July 26, 2019, Kimbell announced a cash distribution of $0.39 per common unit, a 5.4% increase compared to the first quarter of 2019.  Kimbell expects substantially all of this 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. 

Financial Highlights

Total second quarter 2019 revenues increased to $31.9 million compared to $10.7 million in the second quarter of 2018, primarily due to a full quarter of production and operating activities from the assets acquired in the Haymaker acquisition, dropdown and Phillips acquisition.  Second quarter 2019 net loss was $20.4 million and net loss attributable to common units was $11.8 million, or $0.54 per common unit, compared to net income attributable to common units of $1.4 million in the second quarter of 2018.  The decrease in net income during the second quarter of 2019 was primarily due to a $28.1 million non-cash impairment expense recorded during the quarter.

Total second quarter 2019 consolidated Adjusted EBITDA grew to $21.6 million, compared to $7.7 million in the second quarter of 2018 (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).  During the second quarter of 2019, average realized price per Bbl of oil was $57.55, per Mcf of natural gas was $2.44, per Bbl of NGLs was $19.55 and per Boe combined was $25.98. 

Kimbell recorded a $28.1 million non-cash impairment expense in the second quarter of 2019, which was primarily attributable to a decline in the 12-month average price of oil and natural gas.  This non-cash impairment expense 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.

General and administrative ("G&A") expenses were $6.2 million in Q2 2019, $4.1 million of which was cash G&A expense or $3.82 per Boe, down from $3.95 per Boe in Q1 2019.  Non-cash G&A in Q2 2019 was $2.1 million or $1.97 per Boe.  Excluding the effect of one-time severance costs of $0.1 million in cash G&A and $0.3 million in non-cash G&A incurred in Q2 2019, cash G&A per Boe was $3.71 and non-cash G&A per Boe was $1.67.

As of June 30, 2019, Kimbell had outstanding 23,094,135 common units and 23,814,342 Class B units.  As of August 7, 2019, Kimbell had outstanding 23,494,135 common units and 23,414,342 Class B units.  The change in the mix between units is due to an exchange of certain Class B units for an equal number of common units following the second quarter of 2019.

Production

Second quarter 2019 average daily production was 11,807 Boe per day.  Production for Q2 2019 was composed of approximately 37% from liquids (25% from oil and 12% from NGLs) and 63% from natural gas on a 6:1 basis.

2019 Guidance

Kimbell reaffirms the financial guidance for 2019 that was provided in its March 25, 2019 press release.

Liquidity

At June 30, 2019, Kimbell's total debt to consolidated Adjusted EBITDA ratio was 1.0x based on Q2 2019 annualized consolidated Adjusted EBITDA.

On May 28, 2019, the borrowing base under Kimbell's revolving credit facility was increased from $200 million to $300 million and total commitments were increased from $200 million to $225 million.  At June 30, 2018, Kimbell had $87.3 million outstanding and $137.7 million in undrawn capacity under the revolving credit facility (or $212.7 million if the accordion feature was exercised).  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.  Kimbell was in compliance with all financial covenants under the revolving credit facility at June 30, 2019.

Hedging

Kimbell hedges its daily production in a manner that approximates the amount of debt and/or preferred equity as a percent of its enterprise value.  As of June 30, 2019, Kimbell had hedged daily oil and natural gas production of approximately 20% of its production.  Please see the supplemental schedule at the end of this news release for hedging details.

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 2019 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 15, 2019 by dialing 201-612-7415 and using the conference ID 13691697#.  A webcast of the call will also be available live and for later replay on Kimbell Royalty Partners' website at http://kimbellrp.investorroom.com under Events and Presentations. 

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 approximately 13 million gross acres in 28 states and in every major onshore basin in the continental United States, including ownership in more than 92,000 gross producing 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. These forward-looking statements involve risks and uncertainties, including risks and uncertainties relating to the tax treatment of Kimbell's distributions, Kimbell's business, prospects for growth and acquisitions and the securities markets generally.  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 Securities and Exchange Commission ("SEC").  These include risks that the anticipated benefits of the Phillips acquisition are not realized, 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 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 regarding 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 assets acquired in the Phillips acquisition; and other risks described in Kimbell's Annual Report on Form 10-K and other filings with 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.

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 is used as a supplemental non-GAAP financial measure by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies.  We believe Adjusted EBITDA is useful because it allows us to more effectively evaluate our operating performance and compare the results of our operations period to period without regard to our financing methods or capital structure.  In addition, management uses Adjusted EBITDA to evaluate cash flow available to pay distributions to our unitholders.  We define Adjusted EBITDA as net income (loss) before interest expense, net of capitalized interest, non-cash unit-based compensation, unrealized gains and losses on commodity derivative instruments, transaction costs, impairment of oil and natural gas properties, income taxes and depreciation and depletion expense.  Adjusted EBITDA is not a measure of net income (loss) or net cash provided by operating activities as determined by GAAP.  We exclude the items listed above from net income (loss) in arriving at Adjusted EBITDA because these amounts can vary substantially from company to company within our 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.  Our computations of Adjusted EBITDA may not be comparable to other similarly titled measures of other companies.  We expect that cash available for distribution for each quarter will generally equal our 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.

 

 

 

 

 

SOURCE Kimbell Royalty Partners, LP