Viper Energy Partners LP, a Subsidiary of Diamondback Energy, Inc., Reports Third Quarter 2020 Financial and Operating Results

November 2, 2020 4:01 PM EST

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MIDLAND, Texas, Nov. 02, 2020 (GLOBE NEWSWIRE) -- Viper Energy Partners LP (NASDAQ: VNOM) (“Viper” or the “Company”), a subsidiary of Diamondback Energy, Inc. (NASDAQ: FANG) (“Diamondback”), today announced financial and operating results for the third quarter ended September 30, 2020.


  • Q3 2020 consolidated net income (including non-controlling interest) of $16.2 million; adjusted net income (as defined and reconciled below) of $7.1 million
  • Consolidated Adjusted EBITDA (as defined and reconciled below) of $40.4 million and cash available for distribution to Viper’s common limited partner units (as reconciled below) of $13.9 million
  • Previously announced Q3 2020 average production of 15,829 bo/d (26,409 boe/d), an increase of 10% from Q2 2020 average daily oil production and 16% year over year
  • Q3 2020 cash distribution of $0.10 per common unit, representing approximately 50% of cash available for distribution; $0.21 per unit of cash available for distribution implies a 12.0% annualized distributable cash flow yield based on the October 30, 2020 unit closing price of $7.01
  • Ended the third quarter with net debt of $599.1 million; total debt down $67.1 million since March 31, 2020, or a 10% reduction over the past six months
  • 108 total gross (4.7 net 100% royalty interest) horizontal wells turned to production on Viper’s acreage during Q3 2020 with an average lateral length of 10,022 feet
  • Initiating average daily production guidance for Q4 2020 and Q1 2021 of 15,250 to 16,250 bo/d (25,500 to 27,000 boe/d)
  • Narrowing full year 2020 average production guidance to 15,750 to 16,000 bo/d (26,000 to 26,500 boe/d)
  • As of October 14, 2020, there were approximately 486 gross horizontal wells in the process of active development on Viper’s acreage, in which Viper expects to own an average 1.4% net royalty interest (6.6 net 100% royalty interest wells)
  • Approximately 431 gross (11.2 net 100% royalty interest) line-of-sight wells that are not currently in the process of active development, but for which Viper has visibility to the potential of future development in coming quarters, based on Diamondback’s current completion schedule and third party operators’ permits
  • Q2 2020 and Q3 2020 distributions reasonably estimated to not constitute dividends for U.S. federal income tax purposes; instead should generally constitute non-taxable reductions to the tax basis

“Viper’s 10% increase in oil production during the third quarter of 2020 was driven primarily by 38 of Diamondback’s 41 completions in the quarter having a roughly 10% average royalty interest net to Viper, as third-party activity remained minimal, again showcasing the differentiated relationship between Diamondback and Viper.  With production already within the high end of our previously guided range, we are confident we will exit 2020 with a strong production rate, positioning Viper well to deliver robust free cash flow in 2021,” stated Travis Stice, Chief Executive Officer of Viper’s General Partner.

Mr. Stice continued, “The advantaged nature of the royalty business model with no required capital expenditures and only minimal operating expenditures, further enhanced by Viper’s best-in-class cost structure, has been highlighted during this severe industry downturn as Viper has been able to reduce total debt by 10% in just the past six months.  As a direct result of this, and because of our confidence in the expected free cash flow to be generated in our forward outlook, the Board has elected to increase our distribution for the third quarter to 50% of our total cash available for distribution, up from 25% previously.  With a currently anticipated forward free cash flow yield of greater than 15%, due primarily to Diamondback’s expected development plan and benefiting from punitive hedges rolling off in 2021, we look forward to continuing to increase our return of capital to unitholders over the coming quarters.”


Viper’s third quarter 2020 average unhedged realized prices were $36.80 per barrel of oil, $1.07 per Mcf of natural gas and $12.44 per barrel of natural gas liquids, resulting in a total equivalent realized price of $25.76/boe.

During the third quarter of 2020, the Company recorded total operating income of $62.9 million and consolidated net income (including non-controlling interest) of $16.2 million.

As of September 30, 2020, the Company had a cash balance of $7.4 million and $453.5 million available under its revolving credit facility. During the third quarter of 2020, the Company repurchased $6.0 million of the outstanding principal of its 5.375% Senior Notes due 2027 (the “Notes) at a 1.5% discount to par value.  Additionally, during the third quarter, Viper repaid $27.0 million in outstanding borrowings under its revolving credit facility, resulting in total debt reduction of $33.0 million.  Since the end of the first quarter of 2020, Viper has now reduced total debt by $67.1 million, or a 10% reduction over this time period.

In connection with its Fall redetermination, expected to close in November 2020, Viper’s lead bank has recommended maintaining the borrowing base at $580.0 million.  As a result, Viper is expected to maintain its elected commitment at $580.0 million.


The Board of Directors of Viper’s General Partner declared a cash distribution for the three months ended September 30, 2020 of $0.10 per common unit.  The distribution is payable on November 19, 2020 to eligible common unitholders of record at the close of business on November 12, 2020.  This distribution represents approximately 50% of total cash available for distribution.

On August 20, 2020, Viper made a cash distribution to its unitholders and subsequently has reasonably estimated that such distribution, as well as the distribution payable on November 19, 2020, should not constitute dividends for U.S. federal income tax purposes.  Rather, these distributions should generally constitute non-taxable reductions to the tax basis of each distribution recipient’s ownership interest in Viper.  The Form 8937 containing additional information may be found on under the “Investor Relations” section of the site.


During the third quarter 2020, there was a resumption of completion activity on our mineral and royalty acreage as commodity prices improved from historic lows witnessed during the second quarter of 2020.  As a result, during the third quarter, Viper estimates that 108 gross (4.7 net 100% royalty interest) horizontal wells with an average royalty interest of 4.3% were turned to production on its existing acreage position with an average lateral length of 10,022 feet. Of these 108 gross wells, Diamondback is the operator of 38 with an average royalty interest of 9.9%, and the remaining 70 gross wells, with an average royalty interest of 1.3%, are operated by third parties.

During the third quarter of 2020, Viper did not complete any acquisitions.  However, during the third quarter, the Company sold 18 net royalty acres in the Permian Basin for an aggregate of approximately $2.1 million, subject to post-closing adjustments.  As a result of the divestitures, Viper’s footprint of mineral and royalty interests as of September 30, 2020 was 24,696 net royalty acres.

The following table summarizes Viper’s gross well information as of October 14, 2020:

 As of October 14, 2020
 DiamondbackOperated ThirdPartyOperated Total
Horizontal wells turned to production:     
Gross wells38 70 108
Net 100% royalty interest wells3.8 0.9 4.7
Average percent net royalty interest9.9% 1.3% 4.3%
Horizontal producing well count:     
Gross wells1,121 3,427 4,548
Net 100% royalty interest wells88.2 52.6 140.8
Average percent net royalty interest7.9% 1.5% 3.1%
Horizontal active development well count:     
Gross wells71 415 486
Net 100% royalty interest wells3.5 3.1 6.6
Average percent net royalty interest5.0% 0.7% 1.4%
Line of sight wells:     
Gross wells110 321 431
Net 100% royalty interest wells7.4 3.9 11.2
Average percent net royalty interest6.7% 1.2% 2.6%

Despite the continued depressed commodity price environment, there continues to be active development across Viper’s asset base, however, near-term activity is expected to be driven primarily by Diamondback operations. The 486 gross wells currently in the process of active development are those wells that have been spud and are expected to be turned to production within approximately the next six to eight months. The 431 line-of-sight wells are those that are not currently in the process of active development, but for which Viper has reason to believe that they will be turned to production within approximately the next 15 to 18 months. The expected timing of these line-of-sight wells is based primarily on permitting by third party operators or Diamondback’s current expected completion schedule. Existing permits or active development of our royalty acreage does not ensure that those wells will be turned to production given the current depressed oil prices.


Below is Viper’s revised guidance for the full year 2020, as well as average production guidance for Q4 2020 and Q1 2021.

 Viper Energy Partners
Q4 2020 / Q1 2021 Net Production - MBo/d15.25 - 16.25
Q4 2020 / Q1 2021 Net Production - MBoe/d25.50 - 27.00
Full Year 2020 Net Production - MBo/d15.75 - 16.00
Full Year 2020 Net Production - MBoe/d26.00 - 26.50
Unit costs ($/boe) 
Depletion$9.50 - $11.00
Cash G&A$0.60 - $0.80
Non-Cash Unit-Based Compensation$0.10 - $0.25
Interest Expense(1)$3.25 - $3.50
Production and Ad Valorem Taxes (% of Revenue)(2)7% - 8%

(1) Assumes actual interest expense through Q3 2020 plus expected interest expense for Q4 2020 assuming $480mm in principal of Sr. Notes and $125mm drawn on the revolver.(2) Includes production taxes of 4.6% for crude oil and 7.5% for natural gas and NGLs and ad valorem taxes.


Viper will host a conference call and webcast for investors and analysts to discuss its results for the third quarter of 2020 on Tuesday, November 3, 2020 at 10:00 a.m. CT.  Participants should call (844) 400-1537 (United States/Canada) or (703) 326-5198 (International) and use the confirmation code 3361815. A telephonic replay will be available from 1:00 p.m. CT on Tuesday, November 3, 2020 through Tuesday, November 10, 2020 at 1:00 p.m. CT.  To access the replay, call (855) 859-2056 (United States/Canada) or (404) 537-3406 (International) and enter confirmation code 3361815.  A live broadcast of the earnings conference call will also be available via the internet at under the “Investor Relations” section of the site.  A replay will also be available on the website following the call.

About Viper Energy Partners LP

Viper is a limited partnership formed by Diamondback to own, acquire and exploit oil and natural gas properties in North America, with a focus on owning and acquiring mineral and royalty interests in oil-weighted basins, primarily the Permian Basin and the Eagle Ford Shale. For more information, please visit

About Diamondback Energy, Inc.

Diamondback is an independent oil and natural gas company headquartered in Midland, Texas focused on the acquisition, development, exploration and exploitation of unconventional, onshore oil and natural gas reserves in the Permian Basin in West Texas. For more information, please visit

Forward-Looking Statements

This news release contains forward-looking statements within the meaning of the federal securities laws.  All statements, other than historical facts, that address activities that Viper assumes, plans, expects, believes, intends or anticipates (and other similar expressions) will, should or may occur in the future are forward-looking statements. The forward-looking statements are based on management’s current beliefs, based on currently available information, as to the outcome and timing of future events, including specifically the statements regarding the current adverse industry and macroeconomic conditions, depressed commodity prices, production levels on properties in which Viper has mineral and royalty interests, any potential regulatory action that may impose production limits on Viper’s royalty acreage, the acquisitions or dispositions, Diamondback’s plans for the acreage discussed above, development activity by other operators, Viper’s cash distribution policy and the impact of the ongoing COVID-19 pandemic. These forward-looking statements involve certain risks and uncertainties that could cause the results to differ materially from those expected by the management of Viper.  Information concerning these risks and other factors can be found in Viper’s filings with the Securities and Exchange Commission, including its Forms 10-K, 10-Q and 8-K, which can be obtained free of charge on the Securities and Exchange Commission’s web site at Viper undertakes no obligation to update or revise any forward-looking statement.

Viper Energy Partners LP
Consolidated Balance Sheets
(unaudited, in thousands, except unit amounts)
 September 30, December 31,
 2020 2019
Current assets:   
Cash and cash equivalents$7,374  $3,602 
Royalty income receivable (net of allowance for credit losses)32,108  58,089 
Royalty income receivable—related party14,911  10,576 
Other current assets371  397 
Total current assets54,764  72,664 
Oil and natural gas interests, full cost method of accounting ($1,452,248 and $1,551,767 excluded from depletion at September 30, 2020 and December 31, 2019, respectively)2,930,869  2,868,459 
Land5,688  5,688 
Accumulated depletion and impairment(398,678) (326,474)
Property, net2,537,879  2,547,673 
Deferred tax asset (net of allowance)  142,466 
Other assets8,057  22,823 
Total assets$2,600,700  $2,785,626 
Liabilities and Unitholders’ Equity   
Current liabilities:   
Accounts payable$95  $ 
Accounts payable—related party  150 
Accrued liabilities20,831  13,282 
Derivative instruments23,263   
Total current liabilities44,189  13,432 
Long-term debt, net597,880  586,774 
Derivative instruments5,487   
Total liabilities647,556  600,206 
Commitments and contingencies   
Unitholders’ equity:   
General partner829  889 
Common units (67,850,632 units issued and outstanding as of September 30, 2020 and 67,805,707 units issued and outstanding as of December 31, 2019)725,625  929,116 
Class B units (90,709,946 units issued and outstanding September 30, 2020 and December 31, 2019)1,055  1,130 
Total Viper Energy Partners LP unitholders’ equity727,509  931,135 
Non-controlling interest1,225,635  1,254,285 
Total equity1,953,144  2,185,420 
Total liabilities and unitholders’ equity$2,600,700  $2,785,626 

Viper Energy Partners LP
Consolidated Statements of Operations
(unaudited, in thousands, except per unit data)
 Three Months Ended September 30, Nine Months Ended September 30,
 20202019 20202019
Operating income:     
Royalty income$62,584  $71,080  $171,857  $201,950 
Lease bonus income40  698  1,685  3,607 
Other operating income318  10  761  15 
Total operating income62,942  71,788  174,303  205,572 
Costs and expenses:     
Production and ad valorem taxes5,049  4,731  14,306  12,812 
Depletion24,780  18,697  72,204  51,408 
General and administrative expenses1,811  1,805  6,160  5,223 
Total costs and expenses31,640  25,233  92,670  69,443 
Income from operations31,302  46,555  81,633  136,129 
Other income (expense):     
Interest expense, net(8,238) (3,827) (24,870) (11,089)
Gain (loss) on derivative instruments, net(5,084)   (47,469)  
Gain (loss) on revaluation of investment(1,984) 336  (8,661) 3,978 
Other income, net188  553  1,111  1,756 
Total other expense, net(15,118) (2,938) (79,889) (5,355)
Income (loss) before income taxes16,184  43,617  1,744  130,774 
Provision for (benefit from) income taxes  (7,480) 142,466  (41,908)
Net income (loss)16,184  51,097  (140,722) 172,682 
Net income (loss) attributable to non-controlling interest16,948  43,151  23,963  128,692 
Net income (loss) attributable to Viper Energy Partners LP$(764) $7,946  $(164,685) $43,990 
Net income (loss) attributable to common limited partner units:     
Basic$(0.01) $0.13  $(2.43) $0.73 
Diluted$(0.01) $0.13  $(2.43) $0.73 
Weighted average number of common limited partner units outstanding:     
Basic67,847  62,645  67,832  60,267 
Diluted67,847  62,678  67,832  60,296 

Viper Energy Partners LP
Consolidated Statements of Cash Flows
(unaudited, in thousands)
 Three Months Ended September 30, Nine Months Ended September 30,
 2020 2019 2020 2019
Cash flows from operating activities:       
Net income (loss)$16,184  $51,097  $(140,722) $172,682 
Adjustments to reconcile net income (loss) to net cash provided by operating activities:       
Provision for (benefit from) income taxes  (7,541) 142,466  (42,077)
Depletion24,780  18,697  72,204  51,408 
(Gain) loss on derivative instruments, net5,084    47,469   
Net cash payments on derivatives(16,164)   (18,718)  
(Gain) loss on extinguishment of debt20    6   
(Gain) loss on revaluation of investment1,984  (336) 8,661  (3,978)
Amortization of debt issuance costs578  235  1,730  676 
Non-cash unit-based compensation275  449  945  1,326 
Changes in operating assets and liabilities:       
Royalty income receivable10  3,531  25,981  (4,465)
Royalty income receivable—related party(13,994) (4,995) (4,335) (10,544)
Accounts payable and accrued liabilities8,476  1,417  7,644  (821)
Accounts payable—related party    (150)  
Income tax payable  61    169 
Other current assets110  (107) 25  (148)
Net cash provided by (used in) operating activities27,343  62,508  143,206  164,228 
Cash flows from investing activities:       
Acquisitions of oil and natural gas interests764  (194,465) (64,508) (319,696)
Funds held in escrow  5,715    (7,500)
Proceeds from sale of assets2,098    2,098   
Proceeds from the sale of investments5,262    5,262   
Net cash provided by (used in) investing activities8,124  (188,750) (57,148) (327,196)
Cash flows from financing activities:       
Proceeds from borrowings under credit facility3,000  197,000  95,000  368,000 
Repayment on credit facility(30,000)   (65,000) (369,500)
Debt issuance costs(46) (91) (90) (349)
Repayment of senior notes(5,910)   (19,697)  
Proceeds from public offerings      340,860 
Public offering costs      (221)
Units purchased for tax withholding(1)   (384) (353)
Distributions to General Partner(20) (20) (60) (60)
Distributions to public(2,015) (29,099) (38,943) (78,590)
Distributions to Diamondback(2,764) (34,400) (53,112) (99,543)
Net cash provided by (used in) financing activities(37,756) 133,390  (82,286) 160,244 
Net increase (decrease) in cash(2,289) 7,148  3,772  (2,724)
Cash and cash equivalents at beginning of period9,663  12,804  3,602  22,676 
Cash and cash equivalents at end of period$7,374  $19,952  $7,374  $19,952 
Supplemental disclosure of cash flow information:       
Interest paid$1,278  $8,500  $19,196  $10,882 

Viper Energy Partners LP
Selected Operating Data
 Three Months EndedSeptember 30, 2020 Three Months EndedJune 30, 2020 Three Months EndedSeptember 30, 2019
Production Data:     
Oil (MBbls)1,456  1,315   1,258 
Natural gas (MMcf)3,111  2,685   1,710 
Natural gas liquids (MBbls)455  467   413 
Combined volumes (MBOE)(1)2,430  2,230   1,956 
Average daily oil volumes (BO/d)(2)15,829  14,453   13,674 
Average daily combined volumes (BOE/d)(2)26,409  24,508   21,266 
Average sales prices(2):     
Oil ($/Bbl)$36.80  $21.00   $51.53 
Natural gas ($/Mcf)$1.07  $0.46   $1.28 
Natural gas liquids ($/Bbl)$12.44  $7.69   $9.84 
Combined ($/BOE)(3)$25.76  $14.55   $36.33 
Oil, hedged ($/Bbl)(4)$27.65  $22.39   $51.53 
Natural gas, hedged ($/Mcf)(4)$0.16  $(1.01)  $1.28 
Natural gas liquids ($/Bbl)(4)$12.44  $7.69   $9.84 
Combined price, hedged ($/BOE)(4)$19.11  $13.60   $36.33 
Average Costs ($/BOE):     
Production and ad valorem taxes$2.08  $1.39   $2.42 
General and administrative - cash component(5)0.63  0.63   0.69 
Total operating expense - cash$2.71  $2.02   $3.11 
General and administrative - non-cash stock compensation expense$0.11  $0.13   $0.23 
Interest expense, net$3.39  $3.44   $1.96 
Depletion$10.20  $10.21   $9.56 

(1) Bbl equivalents are calculated using a conversion rate of six Mcf per one Bbl.(2) Average daily volumes and average sales prices presented are based on actual production volumes and not calculated utilizing the rounded production volumes presented in the table above.(3) Realized price net of all deducts for gathering, transportation and processing.(4) Hedged prices reflect the effect of our matured commodity derivative transactions on our average sales prices. Our calculation of such effects includes realized gains and losses on cash settlements for commodity derivatives, which we do not designate for hedge accounting. We did not have any derivative contracts prior to February of 2020.(5) Excludes non-cash stock compensation for the respective periods presented.


Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies.  Viper defines Adjusted EBITDA as net income (loss) plus interest expense, net, non-cash unit-based compensation expense, depletion, (gain) loss on revaluation of investments, non-cash (gain) loss on derivative instruments, (gain) loss on extinguishment of debt and provision for (benefit from) income taxes, if any. Adjusted EBITDA is not a measure of net income as determined by United States’ generally accepted accounting principles (“GAAP”).  Management believes Adjusted EBITDA is useful because it allows them to more effectively evaluate Viper’s operating performance and compare the results of its operations from period to period without regard to its financing methods or capital structure. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, net income, royalty income, cash flow from operating activities or any other measure of financial performance or liquidity presented as determined in accordance with GAAP. 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 the historic costs of depreciable assets, none of which are components of Adjusted EBITDA.  Viper defines cash available for distribution generally as an amount equal to its Adjusted EBITDA for the applicable quarter less cash needed for income taxes payable, debt service, contractual obligations, fixed charges and reserves for future operating or capital needs that the board of directors of Viper’s general partner may deem appropriate, common units repurchased for tax withholding, dividend equivalent rights and preferred distributions. Viper’s computations of Adjusted EBITDA and cash available for distribution may not be comparable to other similarly titled measures of other companies or to such measure in its credit facility or any of its other contracts.

The following tables present a reconciliation of the non-GAAP financial measures of Adjusted EBITDA and cash available for distribution to the GAAP financial measure of net loss.

Viper Energy Partners LP
(unaudited, in thousands, except per unit data)
 Three Months EndedSeptember 30, 2020
Net income (loss)$16,184 
Interest expense, net8,238 
Non-cash unit-based compensation expense275 
(Gain) loss on revaluation of investment1,984 
Non-cash (gain) loss on derivative instruments(11,080)
(Gain) loss on extinguishment of debt20 
Consolidated Adjusted EBITDA40,401 
Less: Adjusted EBITDA attributable to non-controlling interest(1)23,113 
Adjusted EBITDA attributable to Viper Energy Partners LP$17,288 
Adjustments to reconcile Adjusted EBITDA to cash available for distribution: 
Debt service, contractual obligations, fixed charges and reserves$(3,297)
Units repurchased for tax withholding(1)
Units - dividend equivalent rights(2)
Preferred distributions(45)
Cash available for distribution to Viper Energy Partners LP unitholders$13,943 
Common limited partner units outstanding67,851 
Cash available for distribution per limited partner unit$0.21 
Cash per unit approved for distribution$0.10 

(1) Does not take into account special income allocation consideration.

Adjusted net income (loss) is a non-GAAP financial measure equal to net income (loss) attributable to Viper adjusted for non-cash (gain) loss on derivative instruments, (gain) loss on revaluation of investments, (gain) loss on extinguishment of debt, valuation for deferred tax asset and related income tax adjustments, if any. The Company’s computation of adjusted net income may not be comparable to other similarly titled measures of other companies or to such measure in our credit facility or any of our other contracts.  

The following table presents a reconciliation of adjusted net income (loss) to net income (loss):

Viper Energy Partners LP
Adjusted Net Income (Loss)
(unaudited, in thousands, except per unit data)
 Three Months Ended September 30, 2020
Net income (loss)$16,184 
Non-cash (gain) loss on derivative instruments, net(11,080)
(Gain) loss on revaluation of investments1,984 
(Gain) loss on extinguishment of debt20 
Adjusted net income (loss)7,108 
Less: Adjusted net income (loss) attributed to non-controlling interests7,317 
Adjusted net income (loss) attributable to Viper Energy Partners LP$(209)
Adjusted net income (loss) attributable to limited partners per common unit$(0.003)


The Partnership defines net debt as debt less cash equivalents. Net debt should not be considered an alternative to, or more meaningful than, total debt, the most directly comparable GAAP measure. Management uses net debt to determine the Partnership's outstanding debt obligations that would not be readily satisfied by its cash and cash equivalents on hand. The Partnership believes this metric is useful to analysts and investors in determining the Partnership's leverage position because the Partnership has the ability to, and may decide to, use a portion of its cash and cash equivalents to reduce debt.

 September 30, 2020 Net Q3 Principal Borrowings/(Repayments) June 30, 2020 March 31, 2020 December 31, 2019 September 30, 2019
 (in thousands)
Total long-term debt(1)$606,438  $(33,000) $639,438  $673,500  $596,500  $409,500 
Cash and cash equivalents(7,374)   (9,663) (40,271) (3,602) (19,952)
Net debt$599,064    $629,775  $633,229  $592,898  $389,548 

(1) Excludes debt issuance, discounts & premiums.


As of the filing date, the Company had the following outstanding derivative contracts. The Company’s derivative contracts are based upon reported settlement prices on commodity exchanges, with crude oil derivative settlements based on New York Mercantile Exchange West Texas Intermediate pricing and Crude Oil Brent and with natural gas derivative settlements based on the New York Mercantile Exchange Henry Hub pricing. When aggregating multiple contracts, the weighted average contract price is disclosed.

 Crude Oil (Bbls/day, $/Bbl)
 Q4 2020 FY 2021
Swaps - WTI (Cushing)1,000   
$27.45  $ 
Collars - WTI (Cushing)14,000  10,000 
Floor Price$28.86  $30.00 
Ceiling Price$32.33  $43.05 
Deferred Premium Call Options - WTI (Cushing)8,000   
Premium$(1.89) $ 
Strike Price ($/Bbl)$45.00  $ 
Basis Swaps - WTI (Midland-Cushing) 4,000    
$(2.60) $ 

 Natural Gas (Mmbtu/day, $/Mmbtu)
 Q4 2020 FY 2021
Natural Gas Basis Swaps - Waha Hub25,000   
$(2.07) $ 

Investor Contacts:Adam Lawlis+1

Austen Gilfillian+1

Source: Viper Energy Partners LP; Diamondback Energy, Inc.

Viper Energy logo

Source: Viper Energy Partners LP

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