Viper Energy Partners LP, a Subsidiary of Diamondback Energy, Inc., Reports Second Quarter 2020 Financial and Operating Results
Viper Energy Partners LP (NASDAQ:VNOM) reported its Q2 2020 results, revealing a consolidated net loss of $(33.1) million and adjusted net loss of $(4.2) million. Average production increased by 9% year-over-year to 14,453 bo/d. The cash distribution was reduced to $0.03 per common unit, approximately 25% of cash available for distribution, to strengthen the balance sheet amid commodity market uncertainty. Viper narrowed its full-year production guidance to 15,250 to 16,000 bo/d, expecting sequential growth supported by Diamondback Energy's operations. Overall, 134 wells turned to production during Q2.
- Average production increased 9% year-over-year to 14,453 bo/d.
- Narrowed full-year production guidance to 15,250 to 16,000 bo/d.
- Strong cash balance of $9.7 million and $426.5 million available under revolving credit.
- Consolidated net loss of $(33.1) million raises financial concerns.
- Cash distribution reduced to $0.03 per unit, signaling potential cash flow issues.
- Limited completion activity reported due to operator responses to oil price volatility.
MIDLAND, Texas, Aug. 03, 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 second quarter ended June 30, 2020.
SECOND QUARTER HIGHLIGHTS
- Q2 2020 consolidated net loss (including non-controlling interest) of
$(33.1) million ; adjusted net loss (as defined and reconciled below) of$(4.2) million - Consolidated Adjusted EBITDA (as defined and reconciled below) of
$26.6 million and cash available for distribution to Viper’s common limited partner units (as reconciled below) of$8.1 million - Q2 2020 average production of 14,453 bo/d (24,508 boe/d), an increase of
9% from Q2 2019 average daily oil production - Q2 2020 cash distribution of
$0.03 per common unit - Due to the current uncertainty in the commodity markets, Viper has temporarily reduced its distribution to approximately
25% of cash available for distribution with the retained cash flow expected to be used to strengthen the balance sheet; the Board of Directors of Viper’s General Partner reviews the distribution policy quarterly - 134 total gross (2.4 net
100% royalty interest) horizontal wells turned to production on Viper’s acreage during Q2 2020 with an average lateral length of 8,648 feet - Initiating average production guidance for Q3 2020 and Q4 2020 of 14,750 to 16,000 bo/d (24,500 to 26,500 boe/d), the midpoint of which is up
6% from Q2 2020 average daily oil production - Narrowing full year 2020 average production guidance to 15,250 to 16,000 bo/d (25,250 to 26,250 boe/d)
- As of July 14, 2020, there were approximately 485 gross horizontal wells currently in the process of active development on Viper’s acreage, in which Viper expects to own an average
1.7% net royalty interest (8.1 net100% royalty interest wells) - Approximately 440 gross (8.8 net
100% royalty interest) line-of-sight wells that are not currently in the process of active development, but for which we have visibility to the potential of future development in coming quarters, based on Diamondback’s current completion schedule and third party operators’ permits - Q1 2020 and Q2 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 production in the second quarter was supported by 14 of Diamondback’s 15 completions in the quarter having more than an
FINANCIAL UPDATE
Viper’s second quarter 2020 average realized prices were
During the second quarter of 2020, the Company recorded total operating income of
As of June 30, 2020, the Company had a cash balance of
SECOND QUARTER 2020 CASH DISTRIBUTION
The Board of Directors of Viper’s General Partner (the “Board”) declared a cash distribution for the three months ended June 30, 2020 of
On May 21, 2020, Viper made a cash distribution to its unitholders and subsequently has reasonably estimated that such distribution, as well as the distribution payable on August 20, 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 www.viperenergy.com under the “Investor Relations” section of the site.
OPERATIONS AND ACQUISITIONS UPDATE
During the second quarter 2020, there was limited completion activity on our mineral and royalty acreage as our operators reacted quickly to oil price volatility by cutting capital expenditures and mostly ceasing completion activity. As a result, during the second quarter, Viper estimates that 134 gross (2.4 net
During the second quarter of 2020, Viper did not complete any acquisitions, leaving its footprint of mineral and royalty interests at a total of 24,714 net royalty acres.
The following table summarizes Viper’s gross well information as of July 14, 2020:
| As of July 14, 2020 | |||||
| Diamondback Operated | Third Party Operated | Total | |||
| Horizontal wells turned to production: | |||||
| Gross wells | 14 | 120 | 134 | ||
| Net | 1.2 | 1.3 | 2.4 | ||
| Average percent net royalty interest | |||||
| Horizontal producing well count: | |||||
| Gross wells | 1,079 | 3,401 | 4,480 | ||
| Net | 84.4 | 51.8 | 136.2 | ||
| Average percent net royalty interest | |||||
| Horizontal active development well count: | |||||
| Gross wells | 66 | 419 | 485 | ||
| Net | 5.2 | 2.9 | 8.1 | ||
| Average percent net royalty interest | |||||
| Line of sight wells: | |||||
| Gross wells | 74 | 366 | 440 | ||
| Net | 4.3 | 4.5 | 8.8 | ||
| Average percent net royalty interest | |||||
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 485 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 440 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.
GUIDANCE UPDATE
Below is Viper’s revised guidance for the full year 2020, as well as average production guidance for Q3 2020 and Q4 2020.
| Viper Energy Partners | |
| Q3 2020 / Q4 2020 Net Production - MBo/d | 14.75 - 16.00 |
| Q3 2020 / Q4 2020 Net Production - MBoe/d | 24.50 - 26.50 |
| Full Year 2020 Net Production - MBo/d | 15.25 - 16.00 |
| Full Year 2020 Net Production - MBoe/d | 25.25 - 26.25 |
| Unit costs ($/boe) | |
| Depletion | |
| Cash G&A | |
| Non-Cash Unit-Based Compensation | |
| Interest Expense (a) | |
| Production and Ad Valorem Taxes (% of Revenue) (b) |
(a) Assumes 1H2020 actual interest expense plus interest expense for the remainder of 2020 assuming
(b) Includes production taxes of
CONFERENCE CALL
Viper will host a conference call and webcast for investors and analysts to discuss its results for the second quarter of 2020 on Tuesday, August 4, 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 6714088. A telephonic replay will be available from 1:00 p.m. CT on Tuesday, August 4, 2020 through Tuesday, August 11, 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 6714088. A live broadcast of the earnings conference call will also be available via the internet at www.viperenergy.com 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 www.viperenergy.com.
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 www.diamondbackenergy.com.
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 recent acquisitions, 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 http://www.sec.gov. 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) | |||||||
| June 30, | December 31, | ||||||
| 2020 | 2019 | ||||||
| Assets | |||||||
| Current assets: | |||||||
| Cash and cash equivalents | $ | 9,663 | $ | 3,602 | |||
| Royalty income receivable (net of allowance for credit losses) | 32,118 | 58,089 | |||||
| Royalty income receivable—related party | 917 | 10,576 | |||||
| Other current assets | 482 | 397 | |||||
| Total current assets | 43,180 | 72,664 | |||||
| Property: | |||||||
| Oil and natural gas interests, full cost method of accounting ( | 2,933,731 | 2,868,459 | |||||
| Land | 5,688 | 5,688 | |||||
| Accumulated depletion and impairment | (373,898 | ) | (326,474 | ) | |||
| Property, net | 2,565,521 | 2,547,673 | |||||
| Deferred tax asset (net of allowance) | — | 142,466 | |||||
| Other assets | 15,572 | 22,823 | |||||
| Total assets | $ | 2,624,273 | $ | 2,785,626 | |||
| Liabilities and Unitholders’ Equity | |||||||
| Current liabilities: | |||||||
| Accounts payable | $ | 11 | $ | — | |||
| Accounts payable—related party | — | 150 | |||||
| Accrued liabilities | 12,439 | 13,282 | |||||
| Derivative instruments | 33,956 | — | |||||
| Total current liabilities | 46,406 | 13,432 | |||||
| Long-term debt, net | 630,507 | 586,774 | |||||
| Derivative instruments | 5,875 | — | |||||
| Total liabilities | 682,788 | 600,206 | |||||
| Commitments and contingencies | |||||||
| Unitholders’ equity: | |||||||
| General partner | 849 | 889 | |||||
| Common units (67,831,342 units issued and outstanding as of June 30, 2020 and 67,805,707 units issued and outstanding as of December 31, 2019) | 728,149 | 929,116 | |||||
| Class B units (90,709,946 units issued and outstanding June 30, 2020 and December 31, 2019) | 1,080 | 1,130 | |||||
| Total Viper Energy Partners LP unitholders’ equity | 730,078 | 931,135 | |||||
| Non-controlling interest | 1,211,407 | 1,254,285 | |||||
| Total equity | 1,941,485 | 2,185,420 | |||||
| Total liabilities and unitholders’ equity | $ | 2,624,273 | $ | 2,785,626 | |||
| Viper Energy Partners LP | |||||||||||||
| Consolidated Statements of Operations | |||||||||||||
| (unaudited, in thousands, except per unit data) | |||||||||||||
| Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||
| 2020 | 2019 | 2020 | 2019 | ||||||||||
| Operating income: | |||||||||||||
| Royalty income | $ | 32,444 | $ | 70,442 | $ | 109,273 | $ | 130,870 | |||||
| Lease bonus income | 23 | 1,749 | 1,645 | 2,909 | |||||||||
| Other operating income | 202 | 3 | 443 | 5 | |||||||||
| Total operating income | 32,669 | 72,194 | 111,361 | 133,784 | |||||||||
| Costs and expenses: | |||||||||||||
| Production and ad valorem taxes | 3,110 | 4,389 | 9,257 | 8,081 | |||||||||
| Depletion | 22,782 | 16,512 | 47,424 | 32,711 | |||||||||
| General and administrative expenses | 1,683 | 1,723 | 4,349 | 3,418 | |||||||||
| Total costs and expenses | 27,575 | 22,624 | 61,030 | 44,210 | |||||||||
| Income from operations | 5,094 | 49,570 | 50,331 | 89,574 | |||||||||
| Other income (expense): | |||||||||||||
| Interest expense, net | (7,669 | ) | (2,713 | ) | (16,632 | ) | (7,262 | ) | |||||
| Loss on derivative instruments, net | (34,443 | ) | — | (42,385 | ) | — | |||||||
| Gain (loss) on revaluation of investment | 3,443 | 50 | (6,677 | ) | 3,642 | ||||||||
| Other income, net | 519 | 547 | 923 | 1,203 | |||||||||
| Total other expense, net | (38,150 | ) | (2,116 | ) | (64,771 | ) | (2,417 | ) | |||||
| (Loss) income before income taxes | (33,056 | ) | 47,454 | (14,440 | ) | 87,157 | |||||||
| Provision for (benefit from) income taxes | — | 180 | 142,466 | (34,428 | ) | ||||||||
| Net (loss) income | (33,056 | ) | 47,274 | (156,906 | ) | 121,585 | |||||||
| Net (loss) income attributable to non-controlling interest | (11,304 | ) | 45,009 | 7,015 | 85,541 | ||||||||
| Net (loss) income attributable to Viper Energy Partners LP | $ | (21,752 | ) | $ | 2,265 | $ | (163,921 | ) | $ | 36,044 | |||
| Net (loss) income attributable to common limited partner units: | |||||||||||||
| Basic | $ | (0.32 | ) | $ | 0.04 | $ | (2.42 | ) | $ | 0.61 | |||
| Diluted | $ | (0.32 | ) | $ | 0.04 | $ | (2.42 | ) | $ | 0.61 | |||
| Weighted average number of common limited partner units outstanding: | |||||||||||||
| Basic | 67,831 | 62,628 | 67,827 | 59,058 | |||||||||
| Diluted | 67,831 | 62,664 | 67,827 | 59,094 | |||||||||
| Viper Energy Partners LP | |||||||||||||||||||||
| Consolidated Statements of Cash Flows | |||||||||||||||||||||
| (unaudited, in thousands) | |||||||||||||||||||||
| Six Months Ended June 30, | |||||||||||||||||||||
| 2020 | 2019 | ||||||||||||||||||||
| Cash flows from operating activities: | |||||||||||||||||||||
| Net (loss) income | $ | (156,906 | ) | $ | 121,585 | ||||||||||||||||
| Adjustments to reconcile net (loss) income to net cash provided by operating activities: | |||||||||||||||||||||
| Provision for (benefit from) income taxes | 142,466 | (34,536 | ) | ||||||||||||||||||
| Depletion | 47,424 | 32,711 | |||||||||||||||||||
| Loss on derivative instruments, net | 42,385 | — | |||||||||||||||||||
| Net cash payments on derivatives | (2,554 | ) | — | ||||||||||||||||||
| Gain on extinguishment of debt | (14 | ) | — | ||||||||||||||||||
| Loss (gain) on revaluation of investment | 6,677 | (3,642 | ) | ||||||||||||||||||
| Amortization of debt issuance costs | 1,152 | 441 | |||||||||||||||||||
| Non-cash unit-based compensation | 670 | 877 | |||||||||||||||||||
| Changes in operating assets and liabilities: | |||||||||||||||||||||
| Royalty income receivable, net | 25,971 | (7,996 | ) | ||||||||||||||||||
| Royalty income receivable—related party | 9,659 | (5,549 | ) | ||||||||||||||||||
| Accounts payable and accrued liabilities | (832 | ) | (2,238 | ) | |||||||||||||||||
| Accounts payable—related party | (150 | ) | — | ||||||||||||||||||
| Income tax payable | — | 108 | |||||||||||||||||||
| Other current assets | (85 | ) | (41 | ) | |||||||||||||||||
| Net cash provided by operating activities | 115,863 | 101,720 | |||||||||||||||||||
| Cash flows from investing activities: | |||||||||||||||||||||
| Acquisitions of oil and natural gas interests | (65,272 | ) | (125,231 | ) | |||||||||||||||||
| Funds held in escrow | — | (13,215 | ) | ||||||||||||||||||
| Net cash used in investing activities | (65,272 | ) | (138,446 | ) | |||||||||||||||||
| Cash flows from financing activities: | |||||||||||||||||||||
| Proceeds from borrowings under credit facility | 92,000 | 171,000 | |||||||||||||||||||
| Repayment on credit facility | (35,000 | ) | (369,500 | ) | |||||||||||||||||
| Debt issuance costs | (44 | ) | (258 | ) | |||||||||||||||||
| Repayment of senior notes | (13,787 | ) | — | ||||||||||||||||||
| Proceeds from public offerings | — | 340,860 | |||||||||||||||||||
| Public offering costs | — | (221 | ) | ||||||||||||||||||
| Units purchased for tax withholding | (383 | ) | (353 | ) | |||||||||||||||||
| Distributions to General Partner | (40 | ) | (40 | ) | |||||||||||||||||
| Distributions to public | (36,928 | ) | (49,491 | ) | |||||||||||||||||
| Distributions to Diamondback | (50,348 | ) | (65,143 | ) | |||||||||||||||||
| Net cash (used in) provided by financing activities | (44,530 | ) | 26,854 | ||||||||||||||||||
| Net increase (decrease) in cash | 6,061 | (9,872 | ) | ||||||||||||||||||
| Cash and cash equivalents at beginning of period | 3,602 | 22,676 | |||||||||||||||||||
| Cash and cash equivalents at end of period | $ | 9,663 | $ | 12,804 | |||||||||||||||||
| Supplemental disclosure of cash flow information: | |||||||||||||||||||||
| Interest paid | $ | 17,918 | $ | 2,382 | |||||||||||||||||
| Viper Energy Partners LP | ||||||||||||||||||
| Selected Operating Data | ||||||||||||||||||
| (unaudited) | ||||||||||||||||||
| Three Months Ended June 30, 2020 | Three Months Ended March 31, 2020 | Three Months Ended June 30, 2019 | ||||||||||||||||
| Production Data: | ||||||||||||||||||
| Oil (MBbls) | 1,315 | 1,587 | 1,202 | |||||||||||||||
| Natural gas (MMcf) | 2,685 | 2,658 | 1,640 | |||||||||||||||
| Natural gas liquids (MBbls) | 467 | 479 | 308 | |||||||||||||||
| Combined volumes (MBOE)(1) | 2,230 | 2,509 | 1,783 | |||||||||||||||
| Average daily oil volumes (BO/d) | 14,453 | 17,441 | 13,205 | |||||||||||||||
| Average daily combined volumes (BOE/d) | 24,508 | 27,575 | 19,597 | |||||||||||||||
| Average sales prices: | ||||||||||||||||||
| Oil ($/Bbl) | $ | 21.00 | $ | 45.49 | $ | 54.81 | ||||||||||||
| Natural gas ($/Mcf) | $ | 0.46 | $ | 0.13 | $ | (0.65 | ) | |||||||||||
| Natural gas liquids ($/Bbl) | $ | 7.69 | $ | 8.94 | $ | 18.33 | ||||||||||||
| Combined ($/BOE)(2) | $ | 14.55 | $ | 30.62 | $ | 39.50 | ||||||||||||
| Oil, hedged ($/Bbl)(3) | $ | 22.39 | $ | 45.49 | $ | 54.81 | ||||||||||||
| Natural gas, hedged ($/Mcf)(3) | $ | (1.01 | ) | $ | (0.04 | ) | $ | (0.65 | ) | |||||||||
| Natural gas liquids ($/Bbl)(3) | $ | 7.69 | $ | 8.94 | $ | 18.33 | ||||||||||||
| Combined price, hedged ($/BOE)(3) | $ | 13.60 | $ | 30.44 | $ | 39.50 | ||||||||||||
| Average Costs ($/BOE): | ||||||||||||||||||
| Production and ad valorem taxes | $ | 1.39 | $ | 2.45 | $ | 2.46 | ||||||||||||
| General and administrative - cash component | 0.63 | 0.91 | 0.70 | |||||||||||||||
| Total operating expense - cash | $ | 2.02 | $ | 3.36 | $ | 3.16 | ||||||||||||
| General and administrative - non-cash component | $ | 0.13 | $ | 0.15 | $ | 0.26 | ||||||||||||
| Interest expense, net | $ | 3.44 | $ | 3.57 | $ | 1.52 | ||||||||||||
| Depletion | $ | 10.21 | $ | 9.82 | $ | 9.26 | ||||||||||||
(1) Bbl equivalents are calculated using a conversion rate of six Mcf per one Bbl.
(2) Realized price net of all deducts for gathering, transportation and processing.
(3) 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.
NON-GAAP FINANCIAL MEASURES
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, loss (gain) on revaluation of investments, non-cash loss (gain) on derivative instruments, gain on extinguishment of debt and provision for (benefit from) income taxes. 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 Ended June 30, 2020 | |||
| Net loss | $ | (33,056 | ) |
| Interest expense, net | 7,669 | ||
| Non-cash unit-based compensation expense | 283 | ||
| Depletion | 22,782 | ||
| Gain on revaluation of investment | (3,443 | ) | |
| Non-cash loss on derivative instruments, net | 32,342 | ||
| Gain on extinguishment of debt | (14 | ) | |
| Consolidated Adjusted EBITDA | 26,563 | ||
| Less: Adjusted EBITDA attributable to non-controlling interest | 15,198 | ||
| Adjusted EBITDA attributable to Viper Energy Partners LP | $ | 11,365 | |
| Adjustments to reconcile Adjusted EBITDA to cash available for distribution: | |||
| Debt service, contractual obligations, fixed charges and reserves | $ | (3,261 | ) |
| Units - dividend equivalent rights | (4 | ) | |
| Preferred distributions | (45 | ) | |
| Cash available for distribution to Viper Energy Partners LP unitholders | $ | 8,055 | |
| Common limited partner units outstanding | 67,831 | ||
| Cash available for distribution per limited partner unit | $ | 0.12 | |
| Cash per unit approved for distribution | $ | 0.03 | |
Adjusted net (loss) income is a non-GAAP financial measure equal to net income attributable to Viper adjusted for non-cash loss (gain) on derivative instruments, (gain) loss on revaluation of investments, gain on extinguishment of debt, valuation for deferred tax asset and related income tax adjustments. 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 loss to net (loss) income:
| Viper Energy Partners LP | |||
| Adjusted Net Income (Loss) | |||
| (unaudited, in thousands, except per unit data) | |||
| Three Months Ended June 30, 2020 | |||
| Net loss | $ | (33,056 | ) |
| Non-cash loss on derivative instruments, net | 32,342 | ||
| Gain on revaluation of investments | (3,443 | ) | |
| Gain on extinguishment of debt | (14 | ) | |
| Adjusted net loss | (4,171 | ) | |
| Less: Adjusted net loss attributed to non-controlling interests | (1,341 | ) | |
| Adjusted net loss attributable to Viper Energy Partners LP | $ | (2,830 | ) |
| Adjusted net loss attributable to limited partners per common unit | $ | (0.04 | ) |
Derivatives
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) | ||||||||||
| Q3 2020 | Q4 2020 | FY 2021 | ||||||||
| Swaps - WTI (Cushing) | 1,000 | 1,000 | — | |||||||
| $ | 27.45 | $ | 27.45 | $ | — | |||||
| Collars - WTI (Cushing) | 14,000 | 14,000 | 10,000 | |||||||
| Floor Price | $ | 28.86 | $ | 28.86 | $ | 30.00 | ||||
| Ceiling Price | $ | 32.33 | $ | 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 | 4,000 | — | |||||||
| $ | (2.60 | ) | $ | (2.60 | ) | $ | — | |||
| Natural Gas (Mmbtu/day, $/Mmbtu) | ||||||||||
| Q3 2020 | Q4 2020 | FY 2021 | ||||||||
| Natural Gas Basis Swaps - Waha Hub | 25,000 | 25,000 | — | |||||||
| $ | (2.07 | ) | $ | (2.07 | ) | $ | — | |||
Investor Contact:
Adam Lawlis
+1 432.221.7467
alawlis@viperenergy.com
Source: Viper Energy Partners LP; Diamondback Energy, Inc.
FAQ
What were Viper Energy Partners' financial results for Q2 2020?
How much is the cash distribution for Viper Energy Partners in Q2 2020?
What is the average production guidance for Viper Energy Partners for Q3 and Q4 2020?
What factors influenced Viper Energy Partners' Q2 2020 results?
How many wells did Viper Energy Partners turn to production in Q2 2020?
