Kimbell Royalty Partners Announces Third Quarter 2020 Results

Well-Positioned to Benefit from Improving Natural Gas Fundamentals

FORT WORTH, Texas, Nov. 5, 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 quarter ended September 30, 2020. 

Third Quarter 2020 Highlights

  • Q3 2020 daily production of 14,160 barrels of oil equivalent ("Boe") per day (6:1)
  • Q3 2020 production was composed of approximately 59% from natural gas and approximately 41% from liquids (28% from oil and 13% from natural gas liquids ("NGL")) (6:1)
  • Q3 2020 oil, natural gas and NGL revenues of $24.3 million, an increase of 45% from Q2 2020, reflecting improved realized commodity prices
  • Q3 2020 realized hedging gains of approximately $675,000; substantial portion of projected oil and natural gas production hedged through Q3 2022
  • Q3 2020 net loss of $25.7 million and Q3 2020 net loss attributable to common units of $17.8 million. The Q3 2020 net loss amount was primarily due to a non-cash ceiling test impairment expense of $22.2 million related to continued substantial weakness in commodity prices
  • Q3 2020 consolidated Adjusted EBITDA of $17.1 million
  • As of September 30, 2020, Kimbell's major properties had 794 gross (2.62 net) drilled but uncompleted wells ("DUCs") and 573 gross (1.84 net) permitted locations on its acreage
  • As of September 30, 2020, Kimbell had 30 rigs actively drilling on its acreage, which represented 12.0%1 market share of all rigs drilling in the continental United States as of such time
  • Announced a Q3 2020 cash distribution of $0.19 per common unit, reflecting a payout ratio of 75% of cash available for distribution; implies a 12.4% annualized yield based on the November 4, 2020 closing price of $6.11 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 revolving credit facility

1 Based on Kimbell rig count of 30 and Baker Hughes U.S. land rig count of 251 as of October 2, 2020.

Robert Ravnaas, Chairman and Chief Executive Officer of Kimbell's general partner commented, "I am very pleased with our third quarter 2020 results, once again proving the resilience of our business model.  Production curtailments, which were put in place by certain operators during the height of the pandemic earlier this year, were largely reversed in the Permian and Eagle Ford during the third quarter of 2020.  However, curtailments were still largely in place on our Bakken assets as of the end of the third quarter of 2020.  We are hopeful that these will also reverse in the fourth quarter of 2020 given improved differentials and commodity prices. 

We are very excited to see the forecasted improvement in natural gas prices both in the fourth quarter of 2020 and full year 2021 based on the futures curve.  With approximately 59% of our daily production from natural gas, this price improvement could have a meaningful positive impact on our future cash flows and quarterly distribution payments.  To put this in perspective, natural gas prices have averaged $2.02 per Mcf so far this year.  The average forecasted natural gas price for full-year 2021 based on the futures curve is $3.03, which if it materializes would be a 50% improvement over 2020 year-to-date natural gas prices.  We have a substantial amount of drilling inventory located across the major natural gas basins in the United States, with a concentration in the core areas of the Haynesville and Marcellus.  We hope to benefit from this significant natural gas drilling inventory for years to come. "

Third Quarter 2020 Distribution and Debt Repayment

On October 23, 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 third quarter of 2020, or $0.19 per common unit.  The distribution will be payable on November 9, 2020 to common unitholders of record at the close of business on November 2, 2020.  The Board of Directors will review the distribution policy quarterly.  Kimbell plans to utilize the remaining 25% of cash available for distribution for the third quarter of 2020 to pay down a portion of the outstanding borrowings under Kimbell's revolving credit facility.

Kimbell expects that substantially all of its third 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 third quarter 2020 average realized price per Bbl of oil was $38.36, per Mcf of natural gas was $1.76, per Bbl of NGLs was $13.42 and per Boe combined was $18.67.

During the third quarter of 2020, the Company's total revenues were $18.4 million, net loss was $25.7 million and net loss attributable to common units was $17.8 million, or $0.50 per common unit.  The net loss during the third quarter of 2020 was primarily due to a $22.2 million non-cash ceiling test impairment expense recorded during the quarter related to the continued 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 third quarter 2020 consolidated Adjusted EBITDA was $17.1 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). 

In the third quarter of 2020, G&A expense was $6.1 million, $3.7 million of which was Cash G&A expense, or $2.81 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 the third quarter of 2020, which is a non-cash G&A expense, was $2.4 million or $1.88 per Boe. 

In spite of further stabilization in the oil and natural gas markets and improved differentials and commodity prices, 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 fourth quarter of 2020.

At September 30, 2020, Kimbell had approximately $169.7 million in debt outstanding under its revolving credit facility, total debt to third quarter 2020 trailing twelve month consolidated Adjusted EBITDA of approximately 2.2x and was in compliance with all financial covenants under its revolving credit facility. 

At the end of the third quarter, Kimbell had 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

Third quarter 2020 average daily production was 14,160 Boe per day (6:1), composed of approximately 59% from natural gas (6:1) and approximately 41% from liquids (28% from oil and 13% from NGLs).

Operational Update

As of September 30, 2020, Kimbell's major properties had 794 gross (2.62 net) DUCs and 573 gross (1.84 net) permitted locations on its acreage.  In addition, as of September 30, 2020, Kimbell had 30 rigs actively drilling on its acreage, which represents an approximate 12.0% market share of all land rigs drilling in the continental United States as of such time.

Basin

Gross DUCs as of September 30, 2020(1)

Gross Permits as of September 30, 2020(1)

Net DUCs as of September 30, 2020(1)

Net Permits as of September 30, 2020(1)

Permian

235

201

0.75

0.61

Mid-Continent

109

70

0.23

0.07

Haynesville

61

19

0.37

0.07

Bakken

150

158

0.12

0.32

Eagle Ford

98

49

0.53

0.34

Appalachia

53

44

0.24

0.14

Rockies

88

32

0.38

0.29

Total

794

573

2.62

1.84
















(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 are time consuming to quantify but, in the experience of Kimbell's management, can be significant in the aggregate.

Hedging Update

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

Kimbell Royalty Partners

Hedge Program








                   Fixed Price Swaps as of September 30, 2020           





Weighted Average



              Volumes

Fixed Price



Oil

Nat Gas

Oil 

Nat Gas



BBL

MMBTU

$/BBL

$/MMBTU


4Q 2020

134,964

1,735,672

$        41.61

$          2.54


1Q 2021

132,030

1,697,940

$        44.43

$          2.83


2Q 2021

133,497

1,716,806

$        44.60

$          2.45


3Q 2021

134,964

1,735,672

$        43.44

$          2.41


4Q 2021

134,964

1,735,672

$        44.58

$          2.49


1Q 2022

132,030

1,697,940

$        36.76

$          2.61


2Q 2022

119,938

1,516,697

$        41.77

$          2.23


3Q 2022

139,196

1,759,316

$        43.52

$          2.44

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 third 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 November 12, 2020, by dialing 201-612-7415 and using the conference ID 13710674#. 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 November 5, 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 Kimbell's financial, operating and production results and prospects for growth, the tax treatment of Kimbell's distributions, future natural gas and other commodity prices, changes to supply and demand for oil, natural gas and NGLs 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

Condensed Consolidated Balance Sheet

(Unaudited, in thousands)



September 30,


2020

Assets:



Current assets



Cash and cash equivalents

$

12,348

Oil, natural gas and NGL receivables


16,039

Accounts receivable and other current assets


947

Total current assets


29,334

Property and equipment, net


1,167

Investment in affiliate (equity method)


4,707

Oil and natural gas properties



Oil and natural gas properties (full cost method)


1,148,983

Less: accumulated depreciation, depletion and impairment


(523,403)

Total oil and natural gas properties, net


625,580

Right-of-use assets, net


3,194

Loan origination costs, net


1,469

Total assets

$

665,451

Liabilities, mezzanine equity and unitholders' equity:



Current liabilities



Accounts payable

$

996

Other current liabilities 


5,843

Commodity derivative liabilities


992

Total current liabilities 


7,831

Operating lease liabilities, excluding current portion


2,919

Commodity derivative liabilities


2,699

Long-term debt


169,701

Total liabilities


183,150

Commitments and contingencies



Mezzanine equity: 



Series A preferred units


42,051

Unitholders' equity: 



Common units


325,048

Class B units


1,039

Total unitholders' equity


326,087

Noncontrolling interest


114,163

Total equity


440,250

Total liabilities, mezzanine equity and unitholders' equity

$

665,451

 

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


September 30, 2020


September 30, 2019

Revenue






Oil, natural gas and NGL revenues

$

24,326


$

29,531

Lease bonus and other income


16



941

(Loss) gain on commodity derivative instruments, net


(5,898)



2,507

Total revenues


18,444



32,979

Costs and expenses 






Production and ad valorem taxes


1,840



2,236

Depreciation and depletion expense


10,705



15,098

Impairment of oil and natural gas properties 


22,237



34,880

Marketing and other deductions


2,512



2,332

General and administrative expenses


6,111



5,695

Total costs and expenses


43,405



60,241

Operating loss


(24,961)



(27,262)

Other income (expense)






Equity income (loss) in affiliate


293



(81)

Interest expense


(1,603)



(1,468)

Other expense


(100)



Net loss before income taxes


(26,371)



(28,811)

(Benefit from) provision for income taxes


(694)



103

Net loss


(25,677)



(28,914)

Distribution and accretion on Series A preferred units


(1,578)



(3,470)

Net loss attributable to noncontrolling interests


9,482



16,146

Distributions on Class B units


(23)



(23)

Net loss attributable to common units

$

(17,796)


$

(16,261)







Basic

$

(0.50)


$

(0.73)

Diluted

$

(0.50)


$

(0.73)

Weighted average number of common units outstanding






Basic


35,423,112



22,399,748

Diluted


35,423,112



22,399,748

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.

Kimbell Royalty Partners, LP

Supplemental Schedules

(Unaudited, in thousands)



Three Months Ended


Three Months Ended


September 30, 2020


September 30, 2019

Reconciliation of net cash provided by operating activities






to Adjusted EBITDA






Net cash provided by operating activities

$

12,379


$

24,835

Interest expense


1,603



1,468

(Benefit from) provision for income taxes


(694)



103

Impairment of oil and natural gas properties


(22,237)



(34,880)

Amortization of right-of-use assets


(70)



(65)

Amortization of loan origination costs


(276)



(266)

Equity income (loss) in affiliate


293



(81)

Forfeiture of restricted units


13



Unit-based compensation


(2,446)



(1,810)

(Loss) gain on commodity derivative instruments, net of settlements


(6,573)



1,684

Changes in operating assets and liabilities:






  Oil, natural gas and NGL revenues receivable


4,273



(1,938)

  Accounts receivable and other current assets


559



64

  Accounts payable


195



11

  Other current liabilities


(1,151)



(1,461)

  Operating lease liabilities


69



91

Consolidated EBITDA

$

(14,063)


$

(12,245)

Add:






Impairment of oil and natural gas properties


22,237



34,880

Unit-based compensation


2,446



1,810

Loss (gain) on commodity derivative instruments, net of settlements


6,573



(1,684)

Cash distribution from affiliate


211



Equity income in affiliate


(293)



Consolidated Adjusted EBITDA

$

17,111


$

22,761

Adjusted EBITDA attributable to noncontrolling interest


(5,953)



(11,349)

Adjusted EBITDA attributable to Kimbell Royalty Partners, LP

$

11,158


$

11,412

 

Kimbell Royalty Partners, LP

Supplemental Schedules

(Unaudited, in thousands, except for per-unit data and unit counts)



Three Months Ended


September 30, 2020




Net loss

$

(25,677)

Depreciation and depletion expense


10,705

Interest expense


1,603

Benefit from income taxes


(694)

Consolidated EBITDA

$

(14,063)

Impairment of oil and natural gas properties


22,237

Unit-based compensation


2,446

Loss on commodity derivative instruments, net of settlements


6,573

Cash distribution from affiliate


211

Equity income in affiliate


(293)

Consolidated Adjusted EBITDA

$

17,111

Adjusted EBITDA attributable to noncontrolling interest


(5,953)

Adjusted EBITDA attributable to Kimbell Royalty Partners, LP

$

11,158




Adjustments to reconcile Adjusted EBITDA to cash available 



for distribution



Cash interest expense


902

Cash distributions on Series A preferred units


628

Distributions on Class B units


23

Cash available for distribution on common units

$

9,605




Common units outstanding on September 30, 2020


38,948,023




Cash available for distribution per common unit outstanding

$

0.25




Common units outstanding on November 2, 2020 Record Date


38,948,023




Third quarter 2020 distribution declared (1)

$

0.19






(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 revolving credit facility. 

 

Kimbell Royalty Partners, LP

Supplemental Schedules

(Unaudited, in thousands, except for per-unit data and unit counts)



Three Months Ended



September 30, 2019






Net loss

$

(28,914)


Depreciation and depletion expense


15,098


Interest expense


1,468


Provision for income taxes


103


Consolidated EBITDA

$

(12,245)


Impairment of oil and natural gas properties


34,880


Unit-based compensation


1,810


Gain on commodity derivative instruments, net of settlements


(1,684)


Consolidated Adjusted EBITDA

$

22,761


Adjusted EBITDA attributable to noncontrolling interest


(11,349)


Adjusted EBITDA attributable to Kimbell Royalty Partners, LP

$

11,412






Adjustments to reconcile Adjusted EBITDA to cash available 




for distribution




Cash interest expense


612


Cash distributions on Series A preferred units


965


Cash income tax expense (1)


147


Distributions on Class B units


23


Cash reserves (1)


(147)


Cash available for distribution on common units

$

9,812






Common units outstanding on September 30, 2019


23,520,219






Cash available for distribution per common unit outstanding

$

0.42






Common units outstanding on November 4, 2019 Record Date


23,520,219






Third quarter 2019 distribution declared

$

0.42








(1)  Reflects cash taxes related to income allocation from the Series A preferred units, which were issued to partially fund the Haymaker acquisition that closed in July 2018.  Kimbell had previously retained cash for post-closing costs and expects to have adequate cash reserves set aside to offset future cash taxes related to the Series A preferred units.

 

Kimbell Royalty Partners, LP

Supplemental Schedules

(Unaudited, in thousands)



Three Months Ended


September 30, 2020




Net loss

$

(25,677)

Depreciation and depletion expense


10,705

Interest expense


1,603

Benefit from income taxes


(694)

Consolidated EBITDA

$

(14,063)

Impairment of oil and natural gas properties


22,237

Unit-based compensation


2,446

Loss on commodity derivative instruments, net of settlements


6,573

Cash distribution from affiliate


211

Equity income in affiliate


(293)

Consolidated Adjusted EBITDA

$

17,111




Q4 2019 - Q2 2020 Consolidated Adjusted EBITDA (1)


61,649

Trailing Twelve Month Consolidated Adjusted EBITDA

$

78,760




Long-term debt (as of 9/30/20)


169,701

Debt to Trailing Twelve Month Consolidated Adjusted EBITDA


2.2x


(1)  The consolidated Adjusted EBITDA for each of the quarters ended December 31, 2019, March 31, 2020 and June 30, 2020 was previously reported in a news release relating to the applicable quarter, and the reconciliation of net loss to consolidated Adjusted EBITDA for each quarter is included in the applicable news release.  This also includes the pro forma results from the Springbok acquisition that closed in April 2020 in accordance with the credit agreement.

 

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SOURCE Kimbell Royalty Partners, LP

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