DocumentRanger Oil Corporation Reports First Quarter Results
Free Cash Flow sets quarterly record
Achieved high end of sales volumes guidance on lower capital investments
Increased mid-point of full-year 2022 sales volumes outlook and reiterated capital guidance
HOUSTON, May 4, 2022 (ACCESSWIRE) – Ranger Oil Corporation (“Ranger” or the “Company”) (NASDAQ:ROCC) today announced financial and operational results for the first quarter of 2022.
First Quarter Highlights
•Achieved upper end of quarterly sales guidance with oil sales of 26,980 barrels per day (“bbl/d”) and total sales of 37,752 barrels of oil equivalent per day (“boe/d”)
•Posted a net loss of $20.7 million and adjusted net income1 of $98.7 million
•Generated Free Cash Flow1 of $64.8 million and $160.9 million of Adjusted EBITDAX1
•Drilling and Completion (“D&C”) capital expenditures were $82.8 million, below the mid-point of guidance
•Strong first quarter sales volumes allowed Company to increase mid-point of full-year 2022 oil and total sales volumes outlook while maintaining annual D&C capital investment guidance of $375 - $425 million
•Maintained strong capital structure with a Net debt/LTM EBITDAX1 ratio <1.0x at quarter-end
Shareholder Return and Free Cash Flow Initiatives
•Authorized $100 million share repurchase program
•Announced accretive “bolt-on” acquisitions in the prolific Eagle Ford shale (Ranger Oil to Acquire Strategic Eagle Ford Assets) totaling approximately $64 million; transactions to be funded with Free Cash Flow
•Plan to initiate annualized dividend of $0.25 per share ($0.0625 per share quarterly) beginning third quarter 2022
“We are off to a great start in 2022 as we continue to execute our business strategy, generate Free Cash Flow and deliver returns for shareholders,” said Ranger President and CEO, Darrin Henke. “Our strong balance sheet, disciplined capital investments, and exceptional operational performance continues, yielding significant Free Cash Flow and allowing us to strengthen our high-margin inventory through recently announced accretive acquisitions.”
First Quarter 2022 Financial and Operating Results
Ranger reported a first quarter 2022 net loss of $20.7 million primarily related to derivative losses of $167.9 million. Adjusted net income1 was $98.7 million for the first quarter of 2022, primarily due to non-cash derivative loss adjustments of $118.9 million. Benefitting from higher commodity prices and disciplined investments, Ranger posted Adjusted EBITDAX1 of $160.9 million and generated quarterly Free Cash Flow of $64.8 million during the quarter.
Total operating expenses for the first quarter of 2022 were $101.0 million, or $29.71 per boe. Adjusted direct operating expenses1, which consist of lease operating expenses (“LOE”), gathering, processing and transportation expenses (“GPT”), production and ad valorem taxes, and adjusted cash general and administrative expenses1 (“G&A”), excluding depreciation, depletion and amortization (“DD&A”) and significant special charges, were $47.4 million, or $13.95 per boe, in the first quarter of 2022. A breakdown of operating expenses, as well as guidance for the remainder of the year, can be found in additional tables included in this release.
Oil sales during the quarter were 26,980 bbl/d, at the upper end of Ranger’s previous guidance (25.8 - 27.0 Mbbl/d). Total sales volumes for the first quarter of 2022 exceeded the mid-point of guidance and were 37,752 boe/d (71% crude oil/86% liquids).
2022 Outlook
Following outperformance in the first quarter, Ranger today increased expectations for the mid-point of its 2022 annual oil and total sales volumes. Ranger’s recent shift to longer lateral wells (full-year 2022E/2023E avg: ~11,000’) is expected to allow for a significant increase in sales volumes in the second half of 2022.
Full-year sales guidance excludes the positive impact from recently announced bolt-on transactions, expected to close early in the third quarter of 2022, subject to customary closing conditions. The Company plans to update full-year guidance following their close.
Ranger reiterated its previously announced D&C capital investment outlook for 2022 of $375 - $425 million.
Henke added, “We are committed to preserving the strength of our balance sheet, making disciplined capital investments, and generating Free Cash Flow to strengthen our business and allow for the return of cash to shareholders. Today, we increased the mid-point of our 2022 outlook for sales volumes while maintaining our original capital guidance. This further demonstrates the fruits of our strategy and confidence in our future.”
The table below sets forth the Company’s operational and financial guidance for the second quarter and full-year 2022:
| | | | | | | | | | | | | | |
| | 2Q 2022 | | Full Year 2022 |
| Total Sales Volumes (boe/d) | | 37,100 – 38,600 | | 39,000 – 41,000 |
| Oil Sales Volumes (bbl/d) | | 26,600 – 27,800 | | 27,500 – 30,000 |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Direct Operating Expenses | | | | |
| LOE (per boe) | | $5.20 - $5.70 | | $5.05 - $5.35 |
| GPT expenses (per boe) | | $2.40 - $2.80 | | $2.25 - $2.55 |
| Ad valorem and production taxes (percent of product revenue) | | 6.0% - 6.5% | | 6.0% - 6.5% |
| Adjusted Cash G&A expenses (per boe) | | $2.25 - $2.75 | | $2.05 - $2.55 |
| | | | |
| Capital Expenditures (millions) | | | | |
| Drilling & Completion | | $110 - $125 | | $375 - $425 |
| Land, Facilities and other | | | | $5 - $10 |
Share Repurchase and Dividend Programs
As previously announced on April 13, 2022, the Board of Directors authorized a $100 million share repurchase program through March 31, 2023.
The Company plans to initiate an annualized dividend of $0.25 per share (0.0625 per share quarterly) beginning in the third quarter of 2022.
Current Balance Sheet and Liquidity
As of April 30, 2022, Ranger had $400 million of senior unsecured notes and approximately $94 million drawn, net of cash, on its revolving credit facility. The Company has a borrowing base of $725 million under its revolving credit facility with elected commitments of $400 million and is currently undergoing its regularly scheduled spring borrowing base redetermination.
1 Adjusted EBITDAX, Free Cash Flow, adjusted net income, Net debt, LTM EBITDAX, adjusted direct operating expenses and adjusted cash G&A are non-GAAP supplemental financial measures. See the definitions and reconciliation to their most comparable GAAP measures within this release.
Conference Call and Webcast Details
A conference call and webcast is planned for 11 am ET on Thursday, May 5, 2022. In addition to the release, supplemental slides will be available on Ranger’s website at www.RangerOil.com.
To participate in the conference call, please dial (844) 707-6931 (international: (412) 317-9248) approximately 10 minutes prior. For the webcast, please log in to Ranger’s website at least 15 minutes prior to the scheduled start time to download supporting materials and install necessary audio software.
A replay of the webcast (available shortly after the call) will be available through May 12, 2022 on the Company's website. The replay will also be available by phone by dialing (877) 344-7529 (international (412) 317-0088) and entering the passcode 1425946. Supplemental slides have been posted to Ranger’s website at www.RangerOil.com.
About Ranger Oil Corporation
Ranger Oil is a pure-play independent oil and gas company engaged in the development and production of oil, NGLs, and natural gas, with operations in the Eagle Ford shale in South Texas. For more information, please visit our website at www.RangerOil.com.
Cautionary Statements Regarding Guidance and Other Matters
The estimates, guidance and planned uses of Free Cash Flow discussed in this release are based on assumptions of current and future capital expenditure levels, prices for oil, NGLs, and natural gas, available liquidity, indications of supply and demand for oil, well results, and operating costs. This release does not constitute any form of guarantee or assurance that the matters indicated will be achieved. While we believe these estimates and the assumptions on which they are based are reasonable as of the date on which they are made, they are inherently uncertain and are subject to, among other things, significant business, economic, operational, and regulatory risks, and uncertainties, some of which are not known as of the date of the statement. Guidance and estimates, and the assumptions on which they are based, are subject to material revision. Actual results may differ materially from estimates and guidance. Further, expectations regarding the announced share repurchase program and anticipated dividends are subject to a variety of factors, including among other things, our earnings, liquidity, capital requirements, financial condition, management’s assessment of the intrinsic value of the Class A Common Stock, the market price of the Company’s Class A Common Stock, general market and economic conditions, available liquidity, compliance with the Company’s debt and other agreements (including maintaining a leverage ratio of no more than 1.0 to 1.0), applicable legal requirements and other factors deemed relevant. Please read the “Forward-Looking Statements” section below, as well as “Risk Factors” in our annual report on Form 10-K and our quarterly reports on Form 10-Q, which are incorporated herein.
Forward-Looking Statements
This communication contains certain “forward-looking” statements within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Statements that are not historical facts are forward-looking statements, and such statements generally include, words such as “anticipate,” “target,” “guidance,” “assumptions,” “projects,” “forward,” “estimates,” “outlook,” “expects,” “continues,”, “project”, “intends,” “plans,” “believes,” “future,” “potential,” “may,” “foresee,” “possible,” “should,” “would,” “could,” “focus” and variations of such words or similar expressions, including the negative thereof, to identify that they are forward-looking statements. Because such statements include assumptions, risks, uncertainties, and contingencies, actual results may differ materially from those expressed or implied by such forward-looking statements. These risks, uncertainties and contingencies include, but are not limited to, the following: the risk that the benefits of the acquisition of Lonestar may not be fully realized or may take longer to realize than expected, and that management attention will be diverted to integration-related issues; risks related to our pending acquisitions, including the risk that a condition to closing of the acquisitions may not be satisfied, that either party may terminate the purchase and sale agreements or that the closing of the acquisitions might be delayed or not occur at all; the impact of the COVID-19 pandemic, including reduced demand for oil and natural gas, economic slowdown, governmental actions, stay-at-home orders, interruptions to our operations or our customer’s operations; risks related to and the impact of actual or anticipated other world health events; our ability to satisfy our short-term and long-term liquidity needs, including our ability to generate sufficient cash flows from operations or to obtain adequate financing; our ability to maintain our relationships with our suppliers, service providers, customers, employees, and other third parties; our ability to execute our business plan in volatile commodity price environments; our ability to develop, explore for, acquire and replace oil and gas reserves and sustain production; changes to our drilling and development program; our ability to generate profits or achieve targeted reserves in our development and exploratory drilling and well operations; our ability to meet guidance, market expectations and internal projections, including type curves; the projected demand for and supply of oil, NGLs and natural gas; our ability to contract for drilling rigs, frac crews, materials, supplies and services at reasonable costs; our ability to renew or replace expiring contracts on acceptable terms; our ability to obtain adequate pipeline transportation capacity or other transportation for our oil and gas production at reasonable cost and to sell our production at, or at reasonable discounts to, market prices; the uncertainties inherent in projecting future rates of production for our wells and the extent to which actual production differs from that estimated in our proved oil and gas reserves; use of new techniques in our development, including choke management and longer laterals; our ability to repurchase shares pursuant to our announced share repurchase program; drilling, completion and operating risks, including adverse impacts associated with well spacing and a high concentration of activity; our ability to convert drilling locations into reserves and production, if at all; the longevity of our currently estimated inventory; approval by our board of directors of any dividends or share repurchases; and other risks set forth in our filings with the SEC, including our most recent Annual Report on Form 10-K and subsequent Quarterly Reports on Form 10-Q. Additional Information concerning these and other factors can be found in our press releases and public filings with the SEC. Many of the factors that will determine our future results are beyond the ability of management to control or predict. In addition, readers should not place undue reliance on forward-looking statements, which reflect management's views only as of the date hereof. The statements in this communication speak only as of the date of the communication. We undertake no obligation to revise or update any forward-looking statements, or to make any other forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by applicable law.
RANGER OIL CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED)
(in thousands, except per share, production and price data)
| | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended | | |
| | March 31, 2022 | | December 31, 2021 | | March 31, 2021 | | | | |
| Revenues and other | | | | | | | | | | |
| Crude oil | | $ | 226,732 | | | $ | 191,079 | | | $ | 81,913 | | | | | |
| Natural gas liquids | | 16,740 | | | 18,328 | | | 3,562 | | | | | |
| Natural gas | | 12,127 | | | 15,187 | | | 2,833 | | | | | |
| Total product revenues | | 255,599 | | | 224,594 | | | 88,308 | | | | | |
| Other operating income, net | | 856 | | | 582 | | | 247 | | | | | |
| Total revenues and other | | 256,455 | | | 225,176 | | | 88,555 | | | | | |
| Operating expenses | | | | | | | | | | |
| Lease operating | | 18,102 | | | 16,202 | | | 8,825 | | | | | |
| Gathering, processing and transportation | | 9,040 | | | 8,112 | | | 4,674 | | | | | |
| Production and ad valorem taxes | | 13,140 | | | 11,273 | | | 5,513 | | | | | |
| General and administrative | | 9,779 | | | 35,435 | | | 13,177 | | | | | |
| Depreciation, depletion and amortization | | 50,893 | | | 48,003 | | | 23,884 | | | | | |
| Impairments of oil and gas properties | | — | | | — | | | 1,811 | | | | | |
| Total operating expenses | | 100,954 | | | 119,025 | | | 57,884 | | | | | |
| Operating income | | 155,501 | | | 106,151 | | | 30,671 | | | | | |
| Other income (expense) | | | | | | | | | | |
| Interest expense, net of amounts capitalized | | (10,697) | | | (11,879) | | | (5,397) | | | | | |
| Gain (loss) on extinguishment of debt | | 2,157 | | | (7,629) | | | (1,231) | | | | | |
| Derivative losses | | (167,887) | | | (17,320) | | | (44,368) | | | | | |
| Other, net | | 76 | | | 107 | | | (6) | | | | | |
| Income (loss) before income taxes | | (20,850) | | | 69,430 | | | (20,331) | | | | | |
| Income tax (expense) benefit | | 189 | | | (1,150) | | | 310 | | | | | |
| Net income (loss) | | (20,661) | | | 68,280 | | | (20,021) | | | | | |
| Net (income) loss attributable to Noncontrolling interest | | 10,676 | | | (34,911) | | | 6,449 | | | | | |
| Net income (loss) attributable to common shareholders | | $ | (9,985) | | | $ | 33,369 | | | $ | (13,572) | | | | | |
| | | | | | | | | | |
| Net income (loss) per share attributable to common shareholders: | | | | | | | | | | |
| Basic | | $ | (0.47) | | | $ | 1.60 | | | $ | (0.89) | | | | | |
| Diluted | | $ | (0.47) | | | $ | 1.56 | | | $ | (0.89) | | | | | |
| | | | | | | | | | |
| Weighted average shares outstanding: | | | | | | | | | | |
| Basic | | 21,107 | | | 20,839 | | | 15,263 | | | | | |
| Diluted | | 21,107 | | | 43,900 | | | 15,263 | | | | | |
RANGER OIL CORPORATION
SELECTED OPERATING STATISTICS (UNAUDITED)
(in thousands, except per share, production and price data)
| | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended | | |
| | March 31, 2022 | | December 31, 2021 | | March 31, 2021 | | | | |
| Total Sales Volume | | | | | | | | | | |
| Crude oil (Mbbl) | | 2,428 | | | 2,532 | | | 1,469 | | | | | |
| NGLs (Mbbl) | | 501 | | | 613 | | | 210 | | | | | |
| Natural gas (MMcf) | | 2,810 | | | 3,345 | | | 1,013 | | | | | |
| Total (Mboe) | | 3,398 | | | 3,702 | | | 1,848 | | | | | |
| Average daily sales volume (boe/d) | | 37,752 | | | 40,236 | | | 20,534 | | | | | |
| | | | | | | | | | |
| Realized Prices | | | | | | | | | | |
| Crude oil ($/bbl) | | $ | 93.38 | | | $ | 75.48 | | | $ | 55.76 | | | | | |
| NGLs ($/bbl) | | $ | 33.40 | | | $ | 29.91 | | | $ | 16.95 | | | | | |
| Natural gas ($/Mcf) | | $ | 4.32 | | | $ | 4.54 | | | $ | 2.80 | | | | | |
| Aggregate ($/boe) | | $ | 75.23 | | | $ | 60.67 | | | $ | 47.79 | | | | | |
| | | | | | | | | | |
Realized Prices, including effects of derivatives, net 1 | | | | | | | | | | |
| Crude oil ($/bbl) | | $ | 74.00 | | | $ | 64.50 | | | $ | 44.80 | | | | | |
| | | | | | | | | | |
| Natural gas ($/Mcf) | | $ | 3.96 | | | $ | 2.99 | | | $ | 2.84 | | | | | |
| Aggregate ($/boe) | | $ | 61.08 | | | $ | 51.77 | | | $ | 39.10 | | | | | |
1 Realized prices, including effects of derivatives, net are non-GAAP measures. Definitions of non-GAAP financial measures and reconciliations of non-GAAP financial measures appear at the end of this release.
RANGER OIL CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)
(in thousands)
| | | | | | | | | | | | | | |
| | March 31, 2022 | | December 31, 2021 |
| Assets | | | | |
| Current assets | | $ | 197,557 | | | $ | 186,151 | |
| Net property and equipment | | 1,417,715 | | | 1,383,348 | |
| Other noncurrent assets | | 7,548 | | | 7,109 | |
| Total assets | | $ | 1,622,820 | | | $ | 1,576,608 | |
| | | | |
| Liabilities and equity | | | | |
| Liabilities | | | | |
| Current liabilities | | $ | 397,122 | | | $ | 268,882 | |
| Other noncurrent liabilities | | 54,593 | | | 36,966 | |
| | | | |
| | | | |
| | | | |
| | | | |
| | | | |
| Total long-term debt, net | | 521,780 | | | 601,252 | |
| Equity | | | | |
| Common shareholders’ equity | | 314,025 | | | 323,532 | |
| Noncontrolling interest | | 335,300 | | | 345,976 | |
| Total equity | | 649,325 | | | 669,508 | |
| Total liabilities and equity | | $ | 1,622,820 | | | $ | 1,576,608 | |
RANGER OIL CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)
(in thousands)
| | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended | | |
| | March 31, 2022 | | December 31, 2021 | | March 31, 2021 | | | | |
| Cash flows from operating activities | | | | | | | | | | |
| Net income (loss) | | $ | (20,661) | | | $ | 68,280 | | | $ | (20,021) | | | | | |
| Adjustments to reconcile net income (loss) to net cash provided by operating activities: | | | | | | | | | | |
| (Gain) loss on extinguishment of debt | | (2,157) | | | 7,629 | | | 1,231 | | | | | |
| Depreciation, depletion and amortization | | 50,893 | | | 48,003 | | | 23,884 | | | | | |
| Impairments of oil and gas properties | | — | | | — | | | 1,811 | | | | | |
| Derivative contracts: | | | | | | | | | | |
| Net losses | | 167,887 | | | 17,320 | | | 44,368 | | | | | |
| Cash settlements and premiums paid, net | | (29,408) | | | (84,434) | | | (7,169) | | | | | |
| Deferred income tax expense (benefit) | | (721) | | | 1,119 | | | (310) | | | | | |
| Non-cash interest expense | | 800 | | | 993 | | | 611 | | | | | |
| Share-based compensation | | 924 | | | 11,410 | | | 2,246 | | | | | |
| Other, net | | (182) | | | 6 | | | 2 | | | | | |
| Changes in operating assets and liabilities, net | | (33,540) | | | 13,992 | | | (13,966) | | | | | |
| Net cash provided by operating activities | | 133,835 | | | 84,318 | | | 32,687 | | | | | |
| | | | | | | | | | |
| Cash flows from investing activities | | | | | | | | | | |
| Acquisitions, net of cash acquired | | — | | | 11,009 | | | — | | | | | |
| Capital expenditures | | (71,173) | | | (109,705) | | | (34,758) | | | | | |
| Proceeds from sales of assets, net | | 656 | | | 3 | | | 4 | | | | | |
| Net cash used in investing activities | | (70,517) | | | (98,693) | | | (34,754) | | | | | |
| | | | | | | | | | |
| Cash flows from financing activities | | | | | | | | | | |
| Proceeds from credit facility borrowings | | 50,000 | | | 50,000 | | | — | | | | | |
| Repayments of credit facility borrowings | | (130,000) | | | (54,900) | | | (85,500) | | | | | |
| Repayments of second lien term loan | | — | | | (143,110) | | | (53,140) | | | | | |
| | | | | | | | | | |
| Repayments of acquired debt | | (83) | | | (249,700) | | | — | | | | | |
| Proceeds from redeemable common units | | — | | | — | | | 151,160 | | | | | |
| Proceeds from redeemable preferred stock | | — | | | — | | | 2 | | | | | |
| Transaction costs paid on behalf of Noncontrolling interest | | — | | | — | | | (5,543) | | | | | |
| Issuance costs paid for Noncontrolling interest securities | | — | | | — | | | (3,758) | | | | | |
| Withholding taxes for share-based compensation | | (445) | | | (33) | | | (476) | | | | | |
| Debt issuance costs paid | | (113) | | | (10,970) | | | (1,830) | | | | | |
| Net cash provided by (used in) financing activities | | (80,641) | | | (408,713) | | | 915 | | | | | |
| Net decrease in cash and cash equivalents | | (17,323) | | | (423,088) | | | (1,152) | | | | | |
| Cash and cash equivalents – beginning of period | | 23,681 | | | 446,769 | | | 13,020 | | | | | |
| Cash and cash equivalents – end of period | | $ | 6,358 | | | $ | 23,681 | | | $ | 11,868 | | | | | |
RANGER OIL CORPORATION
CERTAIN NON-GAAP FINANCIAL MEASURES (UNAUDITED)
Readers are reminded that non-GAAP measures are merely a supplement to, and not a replacement for, or superior to financial measures prepared according to GAAP. They should be evaluated in conjunction with the GAAP financial measures. It should be noted as well that our non-GAAP information may be different from the non-GAAP information provided by other companies.
Reconciliation of GAAP “Realized prices” to Non-GAAP “Realized prices, including effects of derivatives, net”
We present our realized prices for crude oil, natural gas and aggregate (including crude oil, NGLs and natural gas), as adjusted for the effects of derivatives, net as we believe these measures are useful to management and stakeholders in determining the effectiveness of our price-risk management program that is designed to reduce the volatility associated with our operations. Realized prices for crude oil, natural gas and aggregate, as adjusted for the effects of derivatives, net, are supplemental financial measures that are not prepared in accordance with generally accepted accounting principles (“GAAP”). The following table presents the calculation of our non-GAAP realized prices for crude oil, natural gas and aggregate, as adjusted for the effects of derivatives, net and reconciles to realized prices for crude oil, natural gas and aggregate determined in accordance with GAAP:
| | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended | | |
| March 31, 2022 | | December 31, 2021 | | March 31, 2021 | | | | |
| Realized crude oil prices ($/bbl) | $ | 93.38 | | | $ | 75.48 | | | $ | 55.76 | | | | | |
| Effects of derivatives, net ($/bbl) | (19.38) | | | (10.98) | | | (10.96) | | | | | |
| Crude oil realized prices, including effects of derivatives, net ($/bbl) | $ | 74.00 | | | $ | 64.50 | | | $ | 44.80 | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| | | | | | | | | |
| Realized natural gas prices ($/Mcf) | $ | 4.32 | | | $ | 4.54 | | | $ | 2.80 | | | | | |
| Effects of derivatives, net ($/Mcf) | (0.36) | | | (1.55) | | | 0.04 | | | | | |
| Natural gas realized prices, including effects of derivatives, net ($/Mcf) | $ | 3.96 | | | $ | 2.99 | | | $ | 2.84 | | | | | |
| | | | | | | | | |
| Aggregate realized prices ($/boe) | $ | 75.23 | | | $ | 60.67 | | | $ | 47.79 | | | | | |
| Effects of derivatives, net ($/boe) | (14.15) | | | (8.90) | | | (8.69) | | | | | |
| Aggregate realized prices, including effects of derivatives, net ($/boe) | $ | 61.08 | | | $ | 51.77 | | | $ | 39.10 | | | | | |
Effects of derivatives includes, as applicable to the period presented: (i) current period commodity derivative settlements (excluding novated and settled Lonestar derivative contracts); (ii) the impact of option premiums paid or received in prior periods related to current period production; (iii) the impact of prior period cash settlements of early-terminated derivatives originally designated to settle against current period production; (iv) the exclusion of option premiums paid or received in current period related to future period production; and (v) the exclusion of the impact of current period cash settlements for early-terminated derivatives originally designated to settle against future period production.
Reconciliation of GAAP “Net income (loss)” to Non-GAAP “Adjusted net income”
Adjusted net income is a non-GAAP financial measure that represents net income (loss) adjusted to include net realized settlements of derivatives and exclude the effects, net of income taxes, of non-cash changes in the fair value of derivatives, impairments of oil and gas properties, net gains and losses on the sales of assets, (gain) loss on extinguishment of debt, acquisition/integration and strategic transaction costs, and organizational restructuring, including severance. We believe that non-GAAP adjusted net income provides meaningful supplemental information regarding our operational performance. This information facilitates management’s internal comparisons to the Company’s historical operating results as well as to the operating results of our competitors. Since management finds this measure to be useful, the Company believes that our investors can benefit by evaluating both non-GAAP and GAAP results. Adjusted net income is not a measure of financial performance under GAAP and should not be considered as a measure of liquidity or as an alternative to net income (loss).
| | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended | | |
| | March 31, 2022 | | December 31, 2021 | | March 31, 2021 | | | | |
| | (in thousands, except per share amounts) |
| Net income (loss) | | $ | (20,661) | | | $ | 68,280 | | | $ | (20,021) | | | | | |
| Adjustments for derivatives: | | | | | | | | | | |
| Net losses | | 167,887 | | | 17,320 | | | 44,368 | | | | | |
Realized settlements, net 1 | | (49,004) | | | (33,941) | | | (16,982) | | | | | |
| Impairments of oil and gas properties | | — | | | — | | | 1,811 | | | | | |
| Gain on sales of assets, net | | (188) | | | (2) | | | (4) | | | | | |
| (Gain) Loss on extinguishment of debt | | (2,157) | | | 7,629 | | | 1,231 | | | | | |
| Acquisition/integration and strategic transaction costs | | 1,743 | | | 16,485 | | | 4,655 | | | | | |
| Organizational restructuring, including severance | | — | | | 128 | | | 239 | | | | | |
| Income tax effect of adjustments | | 1,072 | | | (128) | | | (539) | | | | | |
Adjusted net income 2 | | $ | 98,692 | | | $ | 75,771 | | | $ | 14,758 | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
1 Realized settlements, net includes, as applicable to the period presented: (i) current period commodity and interest rate derivative settlements (excluding novated and settled Lonestar derivative contracts); (ii) the impact of option premiums paid or received in prior periods related to current period production; (iii) the impact of prior period cash settlements of early-terminated derivatives originally designated to settle against current period production; (iv) the exclusion of option premiums paid or received in current period related to future period production; and (v) the exclusion of the impact of current period cash settlements for early-terminated derivatives originally designated to settle against future period production.
2 Adjusted net income includes the adjusted net income attributable to noncontrolling interest for all periods presented.
Reconciliation of GAAP “Net income (loss)” to Non-GAAP “Adjusted EBITDAX” - Actual
Adjusted EBITDAX represents net income (loss) before (gain) loss on extinguishment of debt, interest expense, income taxes, impairments of oil and gas properties, depreciation, depletion and amortization expense and share-based compensation expense, further adjusted to include the net commodity realized settlements of derivatives and exclude the effects of gains and losses on sales of assets, non-cash changes in the fair value of derivatives, and special items including acquisition/integration and strategic transaction costs, and organizational restructuring, including severance. We believe this presentation is commonly used by investors and professional research analysts for the valuation, comparison, rating, investment recommendations of companies within the oil and gas exploration and production industry. We use this information for comparative purposes within our industry. Adjusted EBITDAX is not a measure of financial performance under GAAP and should not be considered as a measure of liquidity or as an alternative to net income (loss). Adjusted EBITDAX as defined by Ranger Oil may not be comparable to similarly titled measures used by other companies and should be considered in conjunction with net income (loss) and other measures prepared in accordance with GAAP, such as operating income or cash flows from operating activities. Adjusted EBITDAX should not be considered in isolation or as a substitute for an analysis of Ranger Oil’s results as reported under GAAP.
| | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended | | |
| March 31, 2022 | | December 31, 2021 | | March 31, 2021 | | | | |
| (in thousands, except per unit amounts) |
| Net income (loss) | $ | (20,661) | | | $ | 68,280 | | | $ | (20,021) | | | | | |
| Adjustments to reconcile to Adjusted EBITDAX: | | | | | | | | | |
| (Gain) Loss on extinguishment of debt | (2,157) | | | 7,629 | | | 1,231 | | | | | |
| Interest expense, net | 10,697 | | | 11,879 | | | 5,397 | | | | | |
| Income tax expense (benefit) | (189) | | | 1,150 | | | (310) | | | | | |
| Impairments of oil and gas properties | — | | | — | | | 1,811 | | | | | |
| Depreciation, depletion and amortization | 50,893 | | | 48,003 | | | 23,884 | | | | | |
| Share-based compensation expense | 924 | | | 11,410 | | | 2,246 | | | | | |
| Gain on sales of assets, net | (188) | | | (2) | | | (4) | | | | | |
| Adjustments for derivatives: | | | | | | | | | |
| Net losses | 167,887 | | | 17,320 | | | 44,368 | | | | | |
Realized commodity settlements, net 1 | (48,066) | | | (32,970) | | | (16,059) | | | | | |
| Adjustment for special items: | | | | | | | | | |
| Acquisition/integration and strategic transaction costs | 1,743 | | | 16,485 | | | 4,655 | | | | | |
| Organizational restructuring, including severance | — | | | 128 | | | 239 | | | | | |
| Adjusted EBITDAX | $ | 160,883 | | | $ | 149,312 | | | $ | 47,437 | | | | | |
| Net income (loss) per boe | $ | (6.08) | | | $ | 18.45 | | | $ | (10.83) | | | | | |
| Adjusted EBITDAX per boe | $ | 47.35 | | | $ | 40.33 | | | $ | 25.67 | | | | | |
1 Realized commodity settlements, net includes, as applicable to the period presented: (i) current period commodity derivative settlements (excluding novated and settled Lonestar derivative contracts); (ii) the impact of option premiums paid or received in prior periods related to current period production; (iii) the impact of prior period cash settlements of early-terminated derivatives originally designated to settle against current period production; (iv) the exclusion of option premiums paid or received in current period related to future period production; and (v) the exclusion of the impact of current period cash settlements for early-terminated derivatives originally designated to settle against future period production.
Reconciliation of GAAP “Net income (loss)” to Non-GAAP “Adjusted EBITDAX” - Pro Forma
Adjusted EBITDAX represents net income (loss) before (gain) loss on extinguishment of debt, interest expense, income taxes, impairments of oil and gas properties, depreciation, depletion and amortization expense and share-based compensation expense, further adjusted to include the net commodity realized settlements of derivatives and exclude the effects of gains and losses on sales of assets, non-cash changes in the fair value of derivatives, and special items including acquisition/integration and strategic transaction costs, and organizational restructuring, including severance. We believe this presentation is commonly used by investors and professional research analysts for the valuation, comparison, rating, investment recommendations of companies within the oil and gas exploration and production industry. We use this information for comparative purposes within our industry. Adjusted EBITDAX is not a measure of financial performance under GAAP and should not be considered as a measure of liquidity or as an alternative to net income (loss). Adjusted EBITDAX as defined by Ranger Oil may not be comparable to similarly titled measures used by other companies and should be considered in conjunction with net income (loss) and other measures prepared in accordance with GAAP, such as operating income or cash flows from operating activities. Adjusted EBITDAX should not be considered in isolation or as a substitute for an analysis of Ranger Oil’s results as reported under GAAP.
| | | | | | | | | | | | | | | | | |
| March 31, 2022 | | | | March 31, 2022 |
| LTM Actual | | Lonestar 1 | | LTM Pro Forma 1 |
| (in thousands, except per unit amounts) |
| Net income (loss) | $ | 98,278 | | | $ | (12,420) | | | $ | 85,858 | |
| Adjustments to reconcile to Adjusted EBITDAX: | | | | | |
| Loss on extinguishment of debt | 5,472 | | | — | | | 5,472 | |
| Interest expense, net | 38,461 | | | 8,637 | | | 47,098 | |
| Income tax expense | 1,681 | | | 127 | | | 1,808 | |
| Impairments of oil and gas properties | — | | | — | | | — | |
| Depreciation, depletion and amortization | 158,666 | | | 13,051 | | | 171,717 | |
| Share-based compensation expense | 14,267 | | | 1,894 | | | 16,161 | |
| Gain on sales of assets, net | (193) | | | — | | | (193) | |
| Adjustments for derivatives: | | | | | |
| Net losses | 260,518 | | | 36,231 | | | 296,749 | |
Realized commodity settlements, net 2 | (122,748) | | | — | | | (122,748) | |
| Adjustment for special items: | | | | | |
| Acquisition/integration and strategic transaction costs | 20,908 | | | 7,931 | | | 28,839 | |
| Organizational restructuring, including severance | 128 | | | 6 | | | 134 | |
| Other, net | — | | | 1,098 | | | 1,098 | |
| Adjusted EBITDAX | $ | 475,438 | | | $ | 56,555 | | | $ | 531,993 | |
| Net income (loss) per boe | $ | 8.40 | | | $ | (5.26) | | | $ | 6.10 | |
| Adjusted EBITDAX per boe | $ | 40.62 | | | $ | 23.93 | | | $ | 37.82 | |
1 LTM Adjusted EBITDAX pro forma for the Lonestar Resources acquisition is derived from the historical periods as reported in Lonestar Resources’ respective Quarterly Report on Form 10-Q for the second quarter of 2021 and includes the use of the financial information for the third quarter of 2021 derived from its general ledger system and reported on the same basis of accounting as applied for prior reported periods.
2 Realized commodity settlements, net includes, as applicable to the period presented: (i) current period commodity derivative settlements (excluding novated and settled Lonestar derivative contracts); (ii) the impact of option premiums paid or received in prior periods related to current period production; (iii) the impact of prior period cash settlements of early-terminated derivatives originally designated to settle against current period production; (iv) the exclusion of option premiums paid or received in current period related to future period production; and (v) the exclusion of the impact of current period cash settlements for early-terminated derivatives originally designated to settle against future period production.
Reconciliation of GAAP “Operating expenses” to Non-GAAP “Adjusted direct operating expenses and Adjusted direct operating expenses per boe”
Adjusted direct operating expenses and adjusted direct operating expenses per boe are supplemental non-GAAP financial measure that exclude certain non-recurring expenses and non-cash expenses. We believe that the non-GAAP measure of Adjusted total direct operating expense per boe is useful to investors because it provides readers with a meaningful measure of our cost profile and provides for greater comparability period-over-period.
| | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended | | |
| March 31, 2022 | | December 31, 2021 | | March 31, 2021 | | | | |
| (in thousands, except per unit amounts) |
| Operating expenses - GAAP | $ | 100,954 | | | $ | 119,025 | | | $ | 57,884 | | | | | |
| Less: | | | | | | | | | |
| Share-based compensation | (924) | | | (11,410) | | | (2,246) | | | | | |
| Impairments of oil and gas properties | — | | | — | | | (1,811) | | | | | |
| Depreciation, depletion and amortization | (50,893) | | | (48,003) | | | (23,884) | | | | | |
| Total cash direct operating expenses | 49,137 | | | 59,612 | | | 29,943 | | | | | |
| Significant special charges: | | | | | | | | | |
| Acquisition/integration and strategic transaction costs | (1,743) | | | (16,485) | | | (4,655) | | | | | |
| Organizational restructuring, including severance | — | | | (128) | | | (239) | | | | | |
| Non-GAAP Adjusted direct operating expenses | $ | 47,394 | | | $ | 42,999 | | | $ | 25,049 | | | | | |
| Operating expenses per boe | $ | 29.71 | | | $ | 32.15 | | | $ | 31.32 | | | | | |
| Total cash direct operating expenses per boe | $ | 14.46 | | | $ | 16.10 | | | $ | 16.20 | | | | | |
| Non-GAAP Adjusted direct operating expenses per boe | $ | 13.95 | | | $ | 11.62 | | | $ | 13.55 | | | | | |
Reconciliation of GAAP “General and administrative expenses” to Non-GAAP “Adjusted cash general and administrative expenses”
Adjusted cash general and administrative expenses is a supplemental non-GAAP financial measure that excludes certain non-recurring expenses and non-cash share-based compensation expense. We believe that the non-GAAP measure of Adjusted cash general and administrative expenses is useful to investors because it provides readers with a meaningful measure of our recurring G&A expense and provides for greater comparability period-over-period.
| | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended | | |
| March 31, 2022 | | December 31, 2021 | | March 31, 2021 | | | | |
| (in thousands, except per unit amounts) |
| GAAP General and administrative expenses | $ | 9,779 | | | $ | 35,435 | | | $ | 13,177 | | | | | |
| Less: Share-based compensation | (924) | | | (11,410) | | | (2,246) | | | | | |
| Significant special charges: | | | | | | | | | |
| Acquisition/integration and strategic transaction costs | (1,743) | | | (16,485) | | | (4,655) | | | | | |
| Organizational restructuring, including severance | — | | | (128) | | | (239) | | | | | |
| Adjusted cash-based general and administrative expenses | $ | 7,112 | | | $ | 7,412 | | | $ | 6,037 | | | | | |
| GAAP General and administrative expenses per boe | $ | 2.88 | | | $ | 9.57 | | | $ | 7.13 | | | | | |
| Adjusted cash general and administrative expenses per boe | $ | 2.09 | | | $ | 2.00 | | | $ | 3.27 | | | | | |
Definition and Explanation of Free Cash Flow
Free Cash Flow is a non-GAAP financial measure that management believes illustrates our ability to generate cash flows from our business that are available to be returned to our providers of financing capital represented primarily by our debt holders as we do not currently have a dividend or share repurchase program. We present Free Cash Flow as the excess (deficiency) of Discretionary cash flow over Capital additions, net. Discretionary cash flow is defined as Adjusted EBITDAX (non-GAAP measure defined and reconciled to GAAP net income above) less interest expense, debt issue costs, other, net and adjustments for income taxes refunded and changes for working capital. Capital additions represent our committed capital expenditure and acquisition transactions, net of any proceeds from the sales or disposition of assets. We believe Free Cash Flow is commonly used by investors and professional research analysts for the valuation, comparison, rating, investment recommendations of companies in many industries. Free Cash Flow should be considered as a supplement to net income as a measure of performance and net cash provided by operating activities as a measure of our liquidity.
| | | | | | | | | | | | | |
| Three Months Ended March 31, 2022 | | | | Twelve Months Ended March 31, 2022 |
| (in thousands) |
| Adjusted EBITDAX, as reported | $ | 160,883 | | | | | $ | 475,438 | |
| Cash interest | (10,957) | | | | | (39,354) | |
| Income taxes paid | — | | | | | (288) | |
| Debt issues costs paid | (113) | | | | | (12,650) | |
| Working capital and other, net | (2,174) | | | | | 39,405 | |
| Discretionary cash flows | 147,639 | | | | | 462,551 | |
| | | | | |
| Capital expenditures, as reported | (83,461) | | | | | (295,796) | |
| Proceeds from asset sales | 656 | | | | | 812 | |
| Sales and use tax refunds | — | | | | | 32 | |
| Capital additions, net | (82,805) | | | | | (294,952) | |
| Non-GAAP Free Cash Flow | $ | 64,834 | | | | | $ | 167,599 | |
| | | | | |
Adjusted Net debt at beginning of period 1 | 586,476 | | | | | 689,241 | |
| Less: Net debt at end of period | (521,642) | | | | | (521,642) | |
| Non-GAAP Free Cash Flow | $ | 64,834 | | | | | $ | 167,599 | |
1 Net debt at the beginning of the period has been adjusted for the net cash effects of the Lonestar Acquisition. See the following table for adjustments to Net debt.
Net Debt
Net debt is a non-GAAP financial measure that is defined as total principal amount of long-term debt, excluding unamortized discount and debt issuance costs, less cash and cash equivalents. Long-term debt excludes non-recourse mortgage debt assumed with the Lonestar Acquisition. The most comparable financial measure to Net debt under GAAP is principal amount of long-term debt. Net debt is used by management as a measure of our financial leverage. Net debt should not be used by investors or others as the sole basis in formulating investment decisions as it does not represent the Company’s actual indebtedness.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| | March 31, 2022 | | December 31, 2021 | | March 31, 2021 |
| | Actual | | Actual | | Actual | | Pro Forma Adjusted 2 |
| | (in thousands) |
| Credit Facility | | $ | 128,000 | | | $ | 208,000 | | | $ | 228,900 | | | $ | 228,900 | |
| 9.25% Senior Notes due 2026 | | 400,000 | | | 400,000 | | | — | | | 400,000 | |
| Second Lien Term Loan, excludes unamortized discount and issue costs | | — | | | — | | | 146,860 | | | 146,860 | |
Other debt 1 | | — | | | 2,157 | | | — | | | — | |
| Lonestar transaction | | — | | | — | | | — | | | (74,651) | |
| Cash and cash equivalents | | (6,358) | | | (23,681) | | | (11,868) | | | (11,868) | |
| Net debt | | $ | 521,642 | | | $ | 586,476 | | | $ | 363,892 | | | $ | 689,241 | |
1 Other debt of $2.2 million was extinguished during the three months ended March 31, 2022.
2 Adjustments attributable to the Lonestar Acquisition and related debt repayments and hedge restructurings include (i) gross proceeds from the 9.25% Senior Notes due 2026 of $400 million, (ii) debt repayments totaling $392.7 million for the Second Lien Term Loan and Lonestar’s debt, (iii) hedge restructuring costs of $49.6 million and (iv) transaction expenses of $28.5 million.
Contact
Investor Relations
Ph: (713) 722-6540
E-Mail: invest@rangeroil.com
