DALLAS, Aug. 03, 2022 (GLOBE NEWSWIRE) — Berry Corporation (bry) (NASDAQ: BRY) (“Berry” or the “Company”) announced second quarter 2022 results, including net income of $43 million or $0.52 per diluted share, Adjusted Net Income
(1)
of $53 million or $0.64 per diluted share, Adjusted EBITDA
(1)
of $110 million and cash flows from operating activities of $111 million. The Board of Directors declared dividends on common stock totaling $0.62 per share.
Quarterly Highlights
- Reported Adjusted EBITDA
(1)
of $110 million, up 15% from Q1 2022 - Generated Discretionary Free Cash Flow
(1)
of $74 million - Repurchased 2 million shares of common stock
- Declared total quarterly dividends of $0.62 per share: $0.56 variable and $0.06 fixed
- Reaffirmed FY 2022 cash dividends expected at $1.60 – $1.90 per share, based on current plan and commodity strip prices
_______
(1) Please see “Non-GAAP Financial Measures and Reconciliations” later in this press release for a reconciliation and more information on these Non-GAAP measures.
“As demonstrated by our second quarter results, Berry continues to deliver impressive cash flows. For the quarter, our combined dividend will be $0.62 and in the same period we successfully repurchased two million shares of Berry stock for $23 million. Since our 2018 IPO, we will have returned over $225 million to shareholders in the form of dividends and share repurchases, which is more than two times the $110 million of net IPO proceeds. In fact, we have repurchased more than 7.5 million shares or nearly 10% of Berry’s outstanding shares over the last few years,” said Trem Smith, Berry Board Chair and CEO.
For the remainder of the year, we currently see our production holding relatively steady and our discretionary free cash flow remaining strong. We are focused on proactively managing our business and adapting to the dynamic macro environment while continuing to uphold our capital return commitments. I’m pleased to announce an exciting development potentially allowing new Thermal Diatomite production. We have encouraging initial results from early testing of two new horizontal wells using a new development concept that takes advantage of existing reservoir energy, and therefore does not require high pressure cyclic steam injection. While the results are still preliminary and additional testing needs to be performed, if ultimately successful this application offers a potentially significant opportunity. We also continue our early stage CCS efforts through signed Letters of Intent to capture and sequester the majority of our direct operational Scope 1 carbon dioxide emissions in California; although these CCS projects remain subject to regulatory approval, we look forward to working with the counter-parties on a solution that benefits all of our stakeholders,” continued Smith.
Second Quarter 2022 Results
Adjusted EBITDA
(1)
, on a hedged basis, was $110 million in the second quarter 2022. This represented a 15% increase compared to $96 million in the first quarter 2022. This increase is largely the result of higher hedged oil prices and improved margins from the well servicing and abandonment segment, partially offset by lower oil and gas volumes and higher GHG prices as that market returned to more normal levels compared to the first quarter.
The Company reported daily production of 26,200 boe/d for the second quarter 2022, compared to 26,700 boe/d for the first quarter of 2022. The sequential decrease was primarily attributed to the divestment of our Colorado asset in the first quarter and shut in production during planned drilling, workover and abandonment activities in California during the second quarter. Production in Utah increased largely as a result of the drilling program during the first half of the year. The Company’s oil production for the second quarter 2022 was 24,000 bbl/d, or 92% of total production, with California production contributing 21,000 boe/d or 80% of total production.
The Company-wide hedged realized oil price for the second quarter 2022 was $83.78 per bbl, a 9% increase from the prior quarter. The California average oil price before hedges for the second quarter 2022 was $107.31 per bbl, reflecting approximately 96% of Brent, which was 15% higher than the $93.16 per bbl in the first quarter 2022, approximately 95% of Brent.
Operating expenses, or OpEx, consists of lease operating expenses (“LOE”), third-party expenses and revenues from electricity generation, transportation and marketing activities, as well as the effect of derivative settlements (received or paid) for gas purchases. On a hedged basis, operating expenses increased slightly by $0.33 per boe or 1% to $25.97 for the second quarter 2022, compared to $25.64 for the first quarter 2022. During the second quarter, non-energy operating expenses increased due to higher workover and field monitoring activity associated with our field optimization program, and well and facility maintenance expenses. A portion of these higher costs was driven by inflation. Energy operating expenses decreased in the second quarter due to lower hedged fuel prices and higher electricity sales, compared to the first quarter 2022.
Total general and administrative expenses were comparable at $23 million for each of the second and first quarters of 2022. Adjusted General and Administrative Expenses
(1)
, which exclude non-cash stock compensation costs and nonrecurring costs, were also comparable at $19 million for the second and first quarters of 2022.
Taxes, other than income taxes were $4.70 per boe for the second quarter compared to $2.74 per boe in the first quarter 2022 with the increase largely due to the GHG prices returning to the higher, more normal levels compared to the first quarter.
For the second quarter 2022, capital expenditures were approximately $34 million on an accrual basis including capitalized overhead and interest and excluding acquisitions and asset retirement obligation spending. Approximately 55% of this capital was directed to California oil operations, and 34% to Utah operations. Additionally, the Company spent approximately $6 million for plugging and abandonment activities in the second quarter 2022. Aggregate capital expenditures in the first half of 2022 were $62 million and the Company expects full year capital will be at the lower end of its guidance range due to a shift in its development plans to reuse existing wellbores.
The operating results for C&J Well Services improved in the second quarter 2022 compared to the first quarter 2022. For this segment in the second and first quarters 2022, respectively, services revenues were $46 million and $40 million, costs of services were $37 million and $33 million, and general and administrative expenses were $3 million each quarter.
At June 30, 2022, the Company had liquidity of $251 million consisting of $58 million cash on hand and $193 million available for borrowings under its RBL Facility.
“It was a strong discretionary free cash flow quarter and, at current commodity prices, we expect to continue to deliver top tier returns,” stated Cary Baetz, Berry’s Executive Vice President and Chief Financial Officer. “Our 2022 guidance ranges remain in place; however, operating expenses are tracking on the higher side of guidance due to an increase in workovers expensed as we optimized our base production as well as incurred some additional costs associated with our new surveillance program. We also expect a slightly lower capital expenditure due primarily to the increase in workovers expensed and lower overall new drill well count for the year.”
Quarterly Dividends
The Company’s Board of Directors declared dividends totaling $0.62 per share on the Company’s outstanding common stock. The variable portion of $0.56 per share was based on second quarter 2022 Discretionary Free Cash Flow
(1)
in accordance with the Company’s Shareholder Return Model. The fixed portion of $0.06 per share was also declared, and both dividends are payable on August 25, 2022 to shareholders of record at the close of business on August 15, 2022.
Subject to approval by the Board on a quarterly basis and depending on a variety of factors, including the Company’s financial condition and results of operations, the Company intends to declare a fixed and variable dividend each quarter.
Full-Year 2022 Guidance
Berry reiterates its previously issued full-year 2022 guidance as follows.
Full-Year 2022 Guidance |
Low |
High |
|||
| Average Daily Production (boe/d) (1) |
25,500 | 27,500 | |||
| Non-Energy Operating Expenses ($/boe) | $13.75 | $14.25 | |||
| Operating Expenses ($/boe) | $20.00 | $22.00 | |||
| Taxes, Other than Income Taxes ($/boe) | $4.50 | $5.50 | |||
| Adjusted General & Administrative (G&A) expenses ($/boe) (2) |
|||||
| Development and Production Segment & Corp | $5.75 | $6.25 | |||
| Well Servicing and Abandonment Segment | ~$1.45 | ||||
| Capital Expenditures ($ millions) | |||||
| Development and Production Segment & Corp | $125 | $135 | |||
| Well Servicing and Abandonment Segment | ~$8 | ||||
| Well Servicing & Abandonment Segment Adjusted EBITDA ($mm) | ~$27 | ||||
______
(1) Oil production is expected to be approximately 92% of total.
(2) Please see “Non-GAAP Financial Measures and Reconciliations” later in this press release for a reconciliation and more information on these Non-GAAP measures.
Earnings Conference Call
The Company will host a conference call to discuss these results:
| Call Date: | Wednesday, August 3, 2022 |
| Call Time: | 11:00 a.m. Eastern Time / 10:00 a.m. Central Time / 8:00 a.m. Pacific Time |
| Join the live listen-only audio webcast at https://edge.media-server.com/mmc/p/yaxee5u6 |
|
If you would like to ask a question on the live call, please preregister at any time using the following link:
https://register.vevent.com/register/BI057ced2ba12c4a29bd9c527438fcde56
Once registered, you will receive the dial-in numbers and a unique PIN number. You may then dial-in or have a call back. When you dial in, you will input your PIN and be placed into the call. If you register and forget your PIN or lose your registration confirmation email, you may simply re-register and receive a new PIN.
A web based audio replay will be available shortly after the broadcast and will be archived at https://ir.bry.com/reports-resources or visit https://edge.media-server.com/mmc/p/yaxee5u6
About Berry Corporation (bry)
Berry is a publicly traded (NASDAQ: BRY) western United States independent upstream energy company with a focus on onshore, low geologic risk, long-lived, conventional oil reserves located primarily in the San Joaquin basin of California, as well as the Uinta basin of Utah. We also have well servicing and abandonment capabilities in California. More information can be found at the Company’s website at bry.com.
Forward-Looking Statements
The information in this press release includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements, other than statements of historical facts, included in this press release that address plans, activities, events, objectives, goals, strategies, or developments that the Company expects, believes or anticipates will or may occur in the future, such as those regarding its business; financial position; liquidity; cash flows (including, but not limited to, Discretionary Free Cash Flow); financial and operating results; capital program; development and production opportunities and plans; operations and business strategy; potential acquisitions and other organic and strategic growth opportunities; reserves; hedging activities; capital expenditures; return of capital; our new shareholder return model; the payment of or improvement of future dividends; future repurchases of stock or debt; capital investments; the ability to execute ESG-related projects, including reduction of our carbon footprint; recovery factors; and other guidance are forward-looking statements. The forward-looking statements in this press release are based upon various assumptions, many of which are based, in turn, upon further assumptions. Although we believe that these assumptions were reasonable when made, these assumptions are inherently subject to significant uncertainties and contingencies which are difficult or impossible to predict and are beyond our control. Therefore, such forward-looking statements involve significant risks and uncertainties that could materially affect our expected results of operations, liquidity, cash flows and business prospects.
Berry cautions you that these forward-looking statements are subject to all of the risks and uncertainties incident to the exploration for and development, production, gathering and sale of natural gas, NGLs and oil most of which are difficult to predict and many of which are beyond Berry’s control. These risks include, but are not limited to, commodity price volatility; legislative and regulatory actions that may prevent, delay or otherwise restrict our ability to drill and develop our assets, including with respect to existing and/or new requirements in the regulatory approval and permitting process; legislative and regulatory initiatives in California or our other areas of operation addressing climate change or other environmental concerns; investment in and development of competing or alternative energy sources; drilling, production and other operating risks; uncertainties inherent in estimating natural gas and oil reserves and in projecting future rates of production; cash flow and access to capital; the timing and funding of development expenditures; environmental, health and safety risks; effects of hedging arrangements; potential shut-ins of production due to lack of downstream demand or storage capacity; disruptions to, capacity constraints in, or other limitations on the third-party transportation and market takeaway infrastructure (including pipeline systems) that deliver our oil and natural gas and other processing and transportation considerations; the impact and duration of the ongoing COVID-19 pandemic on demand and pricing levels; the ability to effectively deploy our ESG strategy and risks associated with initiating new projects or business in connection therewith; overall domestic and global political and economic conditions; inflation levels, particularly the recent rise to historically high levels, and government efforts to reduce inflation, including increased interest rates; and the other risks described under the heading “Item 1A. Risk Factors” in the Company’s Annual Report on Form 10-K for the year ended December 31, 2021 and subsequent filings with the SEC.
You can typically identify forward-looking statements by words such as aim, anticipate, achievable, believe, budget, continue, could, effort, estimate, expect, forecast, goal, guidance, intend, likely, may, might, objective, outlook, plan, potential, predict, project, seek, should, target, will or would and other similar words that reflect the prospective nature of events or outcomes.
Any forward-looking statement speaks only as of the date on which such statement is made, and we undertake no obligation to correct or update any forward-looking statement, whether as a result of new information, future events or otherwise except as required by applicable law. Investors are urged to consider carefully the disclosure in our filings with the Securities and Exchange Commission, available from us at via our website or via the Investor Relations contact below, or from the SEC’s website at www.sec.gov.
Tables Following
The financial information and certain other information presented have been rounded to the nearest whole number or the nearest decimal. Therefore, the sum of the numbers in a column may not conform exactly to the total figure given for that column in certain tables. In addition, certain percentages presented here reflect calculations based upon the underlying information prior to rounding and, accordingly, may not conform exactly to the percentages that would be derived if the relevant calculations were based upon the rounded numbers, or may not sum due to rounding.
SUMMARY OF RESULTS
Three Months Ended |
|||||||||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||||||||
($ and shares in thousands, except per share amounts) |
|||||||||||
Statement of Operations Data: |
|||||||||||
Revenues and other: |
|||||||||||
| Oil, natural gas and natural gas liquids sales | $ | 240,071 | $ | 210,351 | $ | 147,775 | |||||
| Services revenue | 46,178 | 39,836 | — | ||||||||
| Electricity sales | 7,419 | 5,419 | 6,888 | ||||||||
| Losses on oil and gas sales derivatives | (40,658 | ) | (161,858 | ) | (55,653 | ) | |||||
| Marketing revenues | — | 289 | 121 | ||||||||
| Other revenues | 120 | 45 | 118 | ||||||||
| Total revenues and other | 253,130 | 94,082 | 99,249 | ||||||||
Expenses and other: |
|||||||||||
| Lease operating expenses | 72,455 | 63,124 | 45,543 | ||||||||
| Costs of services | 36,709 | 33,472 | — | ||||||||
| Electricity generation expenses | 6,122 | 4,463 | 4,712 | ||||||||
| Transportation expenses | 1,108 | 1,158 | 1,757 | ||||||||
| Marketing expenses | — | 299 | 44 | ||||||||
| General and administrative expenses | 23,183 | 22,942 | 16,065 | ||||||||
| Depreciation, depletion and amortization | 38,055 | 39,777 | 35,850 | ||||||||
| Taxes, other than income taxes | 11,214 | 6,605 | 11,603 | ||||||||
| Losses (gains) on natural gas purchase derivatives | 10,661 | (29,054 | ) | (11,639 | ) | ||||||
| Other operating expenses | 353 | 3,769 | 42 | ||||||||
| Total expenses and other | 199,860 | 146,555 | 103,977 | ||||||||
Other (expenses) income: |
|||||||||||
| Interest expense | (7,729 | ) | (7,675 | ) | (8,217 | ) | |||||
| Other, net | (42 | ) | (13 | ) | (8 | ) | |||||
| Total other (expenses) income | (7,771 | ) | (7,688 | ) | (8,225 | ) | |||||
Income (loss) before income taxes |
45,499 | (60,161 | ) | (12,953 | ) | ||||||
| Income tax expense (benefit) | 2,145 | (3,351 | ) | (72 | ) | ||||||
Net income (loss) |
$ | 43,354 | $ | (56,810 | ) | $ | (12,881 | ) | |||
Net income (loss) per share: |
|||||||||||
| Basic | $ | 0.54 | $ | (0.71 | ) | $ | (0.16 | ) | |||
| Diluted | $ | 0.52 | $ | (0.71 | ) | $ | (0.16 | ) | |||
| Weighted-average shares of common stock outstanding – basic | 79,596 | 80,298 | 80,471 | ||||||||
| Weighted-average shares of common stock outstanding – diluted | 83,015 | 80,298 | 80,471 | ||||||||
| Adjusted Net Income (Loss) (1) |
$ | 53,136 | $ | 42,871 | $ | (6,293 | ) | ||||
| Weighted-average shares of common stock outstanding – diluted | 83,015 | 84,447 | 80,471 | ||||||||
| Diluted earnings per share on Adjusted Net Income (Loss) | $ | 0.64 | $ | 0.51 | $ | (0.08 | ) | ||||
Three Months Ended |
|||||||||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||||||||
($ and shares in thousands, except per share amounts) |
|||||||||||
| Adjusted EBITDA (1) |
$ | 109,747 | $ | 95,712 | $ | 40,599 | |||||
| Adjusted EBITDA Unhedged (1) |
$ | 147,375 | $ | 127,864 | $ | 78,030 | |||||
| Adjusted General and Administrative Expenses (1) |
$ | 18,920 | $ | 19,038 | $ | 13,302 | |||||
| Effective Tax Rate, including discrete items | 5 | % | 5 | % | 1 | % | |||||
Cash Flow Data: |
|||||||||||
| Net cash provided by operating activities | $ | 111,242 | $ | 48,530 | $ | 21,429 | |||||
| Net cash used in investing activities | $ | (38,863 | ) | $ | (36,560 | ) | $ | (40,575 | ) | ||
| Net cash used in financing activities | $ | (37,844 | ) | $ | (9,293 | ) | $ | (3,298 | ) | ||
__________
(1) See further discussion and reconciliation in “Non-GAAP Financial Measures and Reconciliations”.
June 30, 2022 |
December 31, 2021 |
||||
($ and shares in thousands) |
|||||
Balance Sheet Data: |
|||||
| Total current assets | $ | 204,898 | $ | 147,498 | |
| Total property, plant and equipment, net | $ | 1,313,927 | $ | 1,301,349 | |
| Total current liabilities | $ | 261,746 | $ | 187,149 | |
| Long-term debt | $ | 395,135 | $ | 394,566 | |
| Total stockholders’ equity | $ | 640,769 | $ | 629,648 | |
| Outstanding common stock shares as of | 78,760 | 80,007 | |||
The following table represents selected financial information for the periods presented regarding the Company’s business segments on a stand-alone basis and the consolidation and elimination entries necessary to arrive at the financial information for the Company on a consolidated basis. Berry acquired C&J Well Services on October 1, 2021 and the results of their operations were included in Berry’s consolidated results beginning the fourth quarter 2021.
Three Months Ended June 30, 2022 |
||||||||||||
Development & Production |
Well Servicing and Abandonment |
Corporate/Eliminations |
Consolidated Company |
|||||||||
(in thousands) |
||||||||||||
| Revenues – excluding hedges | $ | 247,610 | $ | 46,178 | $ | — | $ | 293,788 | ||||
| Net income (loss) | $ | 68,885 | $ | 3,307 | $ | (28,838 | ) | $ | 43,354 | |||
| Adjusted EBITDA | $ | 116,942 | $ | 6,200 | $ | (13,395 | ) | $ | 109,747 | |||
| Capital expenditures | $ | 32,134 | $ | 1,066 | $ | 886 | $ | 34,086 | ||||
| Total assets | $ | 1,456,164 | $ | 71,543 | $ | 2,678 | $ | 1,530,385 | ||||
Three Months Ended March 31, 2022 |
|||||||||||||||
Development & Production |
Well Servicing and Abandonment |
Corporate/Eliminations |
Consolidated Company |
||||||||||||
(in thousands) |
|||||||||||||||
| Revenues – excluding hedges | $ | 216,104 | $ | 39,836 | $ | — | $ | 255,940 | |||||||
| Net loss before income taxes | $ | (34,291 | ) | $ | (284 | ) | $ | (25,586 | ) | $ | (60,161 | ) | |||
| Adjusted EBITDA | $ | 105,649 | $ | 3,300 | $ | (13,237 | ) | $ | 95,712 | ||||||
| Capital expenditures | $ | 26,437 | $ | 628 | $ | 555 | $ | 27,620 | |||||||
| Total assets | $ | 1,471,358 | $ | 73,887 | $ | (50,518 | ) | $ | 1,494,727 | ||||||
SUMMARY BY AREA
The following table shows a summary by area of our selected historical information and operating information for our development and production operations for the periods indicated.
California
|
|||||||||||
Three Months Ended |
|||||||||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||||||||
($ in thousands, except prices) |
|||||||||||
| Oil, natural gas and natural gas liquids sales | $ | 204,706 | $ | 186,252 | $ | 129,128 | |||||
| Operating income (1) |
$ | 63,608 | $ | 60,162 | $ | 11,413 | |||||
| Depreciation, depletion, and amortization (DD&A) | $ | 34,074 | $ | 35,786 | $ | 35,174 | |||||
| Average daily production (mboe/d) | 21.0 | 22.2 | 21.7 | ||||||||
| Production (oil % of total) | 100 | % | 100 | % | 100 | % | |||||
| Realized sales prices: | |||||||||||
| Oil (per bbl) | $ | 107.31 | $ | 93.16 | $ | 65.37 | |||||
| NGLs (per bbl) | $ | — | $ | — | $ | — | |||||
| Gas (per mcf) | $ | — | $ | — | $ | — | |||||
| Capital expenditures (2) |
$ | 18,672 | $ | 14,622 | $ | 31,303 | |||||
Utah
|
Colorado (Piceance basin) (4) |
||||||||||||||||||||||
Three Months Ended |
Three Months Ended |
||||||||||||||||||||||
June 30,
|
March 31, 2022 |
June 30,
|
June 30,
|
March 31, 2022 |
June 30,
|
||||||||||||||||||
($ in thousands, except prices) |
|||||||||||||||||||||||
| Oil, natural gas and natural gas liquids sales | $ | 35,338 | $ | 23,038 | $ | 16,199 | $ | — | $ | 1,056 | $ | 2,438 | |||||||||||
| Operating income (1) |
$ | 20,579 | $ | 11,173 | $ | 6,736 | $ | — | $ | 610 | $ | 1,121 | |||||||||||
| Depreciation, depletion, and amortization (DD&A) | $ | 964 | $ | 803 | $ | 630 | $ | — | $ | 9 | $ | 38 | |||||||||||
| Average daily production (mboe/d) | 5.2 | 4.1 | 4.4 | — | 0.4 | 1.2 | |||||||||||||||||
| Production (oil % of total) | 57 | % | 53 | % | 52 | % | — | % | — | % | 2 | % | |||||||||||
| Realized sales prices: | |||||||||||||||||||||||
| Oil (per bbl) | $ | 94.47 | $ | 83.02 | $ | 58.55 | $ | — | $ | 89.41 | $ | 56.05 | |||||||||||
| NGLs (per bbl) | $ | 56.47 | $ | 47.03 | $ | 29.61 | $ | — | $ | — | $ | — | |||||||||||
| Gas (per mcf) | $ | 7.35 | $ | 5.93 | $ | 3.30 | $ | — | $ | 5.12 | $ | 3.53 | |||||||||||
| Capital expenditures (2) |
$ | 11,563 | $ | 9,752 | $ | 9,162 | $ | — | $ | — | $ | — | |||||||||||
__________
(1) Operating income (loss) includes oil, natural gas and NGL sales, marketing revenues, other revenues, and scheduled oil derivative settlements, offset by operating expenses (as defined elsewhere), general and administrative expenses, DD&A, impairment of oil and gas properties, and taxes, other than income taxes.
(2) Excludes corporate capital expenditures.
(3) Our Placerita properties, in the Ventura basin, were divested in October 2021.
(4) Our properties in Colorado were in the Piceance basin, all of which were divested in January 2022.
COMMODITY PRICING
Three Months Ended |
|||||||||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||||||||
Weighted-average realized sales prices: |
|||||||||||
| Oil without hedges ($/bbl) | $ | 105.70 | $ | 92.25 | $ | 64.72 | |||||
| Effects of scheduled derivative settlements ($/bbl) | $ | (21.92 | ) | $ | (15.38 | ) | $ | (18.33 | ) | ||
| Oil with hedges ($/bbl) | $ | 83.78 | $ | 76.87 | $ | 46.39 | |||||
| Natural gas ($/mcf) | $ | 7.35 | $ | 5.77 | $ | 3.39 | |||||
| NGLs ($/bbl) | $ | 56.47 | $ | 47.03 | $ | 29.61 | |||||
Average Benchmark prices: |
|||||||||||
| Oil (bbl) – Brent | $ | 111.98 | $ | 97.90 | $ | 69.08 | |||||
| Oil (bbl) – WTI | $ | 108.71 | $ | 94.54 | $ | 66.03 | |||||
| Natural gas (mmbtu) – Kern, Delivered (1) |
$ | 7.36 | $ | 4.83 | $ | 3.23 | |||||
| Natural gas (mmbtu) – Henry Hub (2) |
$ | 7.50 | $ | 4.67 | $ | 2.95 | |||||
__________
(1) Kern, Delivered Index is the relevant index used for gas purchases in California.
(2) Henry Hub is the relevant index used for gas sales in the Rockies.
CURRENT HEDGING SUMMARY
As of June 30, 2022, we had the following hedges for our crude oil production and gas purchases.
Q3 2022 |
Q4 2022 |
FY 2023 |
FY 2024 |
FY 2025 |
||||||||||
Brent |
||||||||||||||
Swaps |
||||||||||||||
| Hedged volume (bbls) | 1,380,000 | 1,288,000 | 3,433,528 | 1,917,000 | — | |||||||||
| Weighted-average price ($/bbl) | $ | 77.73 | $ | 76.07 | $ | 73.06 | $ | 75.52 | $ | — | ||||
Put Spreads |
||||||||||||||
| Hedged volume (bbls) | 368,000 | 368,000 | 2,190,000 | 1,281,000 | — | |||||||||
| Weighted-average price ($/bbl) | $50.00/$40.00 | $50.00/$40.00 | $50.00/$40.00 | $50.00/$40.00 | $ | — | ||||||||
Producer Collars |
||||||||||||||
| Hedged volume (bbls) | — | — | 1,460,000 | 1,098,000 | — | |||||||||
| Weighted-average price ($/bbl) | $ | — | $ | — | $40.00/$106.00 | $40.00/$105.00 | $ | — | ||||||
Henry Hub – Natural Gas purchases |
||||||||||||||
Consumer Collars |
||||||||||||||
| Hedged volume (mmbtu) | 3,680,000 | 3,680,000 | 5,430,000 | — | — | |||||||||
| Weighted-average price ($/mmbtu) | $4.00/$2.75 | $4.00/$2.75 | $4.00/$2.75 | $ | — | $ | — | |||||||
NWPL – Natural Gas purchases |
||||||||||||||
Swaps |
||||||||||||||
| Hedged volume (mmbtu) | — | 1,220,000 | 12,800,000 | 7,320,000 | 6,080,000 | |||||||||
| Weighted-average price ($/mmbtu) | $ | — | $ | 6.40 | $ | 5.48 | $ | 4.27 | $ | 4.27 | ||||
OPERATING EXPENSES
Three Months Ended |
|||||||||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||||||||
($ in thousands except per boe amounts) |
|||||||||||
| Lease operating expenses | $ | 72,455 | $ | 63,124 | $ | 45,543 | |||||
| Electricity generation expenses | 6,122 | 4,463 | 4,712 | ||||||||
| Electricity sales (1) |
(7,419 | ) | (5,419 | ) | (6,888 | ) | |||||
| Transportation expenses | 1,108 | 1,158 | 1,757 | ||||||||
| Transportation sales (1) |
(120 | ) | (45 | ) | (118 | ) | |||||
| Marketing expenses | — | 299 | 44 | ||||||||
| Marketing revenues (1) |
— | (289 | ) | (121 | ) | ||||||
| Derivative settlements (received) paid for gas purchases (1) |
(10,188 | ) | (1,653 | ) | (1,913 | ) | |||||
| Total operating expenses (1) |
$ | 61,958 | $ | 61,638 | $ | 43,016 | |||||
| Lease operating expenses ($/boe) | $ | 30.37 | $ | 26.25 | $ | 18.33 | |||||
| Electricity generation expenses ($/boe) | 2.57 | 1.86 | 1.90 | ||||||||
| Electricity sales ($/boe) | (3.11 | ) | (2.25 | ) | (2.77 | ) | |||||
| Transportation expenses ($/boe) | 0.46 | 0.48 | 0.70 | ||||||||
| Transportation sales ($/boe) | (0.05 | ) | (0.02 | ) | (0.05 | ) | |||||
| Marketing expenses ($/boe) | — | 0.13 | 0.02 | ||||||||
| Marketing revenues ($/boe) | — | (0.12 | ) | (0.05 | ) | ||||||
| Derivative settlements (received) paid for gas purchases ($/boe) | (4.27 | ) | (0.69 | ) | (0.77 | ) | |||||
| Total operating expenses ($/boe) | $ | 25.97 | $ | 25.64 | $ | 17.31 | |||||
| Total unhedged operating expenses ($/boe) (2) |
$ | 30.24 | $ | 26.33 | $ | 18.08 | |||||
| Total non-energy operating expenses (3) |
$ | 16.10 | $ | 13.58 | $ | 12.71 | |||||
| Total energy operating expenses (4) |
$ | 9.87 | $ | 12.06 | $ | 4.60 | |||||
| Total mboe | 2,386 | 2,406 | 2,485 | ||||||||
__________
(1) We report electricity, transportation and marketing sales separately in our financial statements as revenues in accordance with GAAP. However, these revenues are viewed and used internally in calculating operating expenses which is used to track and analyze the economics of development projects and the efficiency of our hydrocarbon recovery. We purchase third-party gas to generate electricity through our cogeneration facilities to be used in our field operations activities and view the added benefit of any excess electricity sold externally as a cost reduction/benefit to generating steam for our thermal recovery operations. Marketing revenues and expenses mainly relate to natural gas purchased from third parties that moves through our gathering and processing systems and then is sold to third parties. Transportation sales relate to water and other liquids that we transport on our systems on behalf of third parties and have not been significant to date. Operating expenses also include the effect of derivative settlements (received or paid) for gas purchases.
(2) Total unhedged operating expenses equals total operating expenses, excluding the derivative settlements paid (received) for gas purchases.
(3) Total non-energy operating expenses equals total operating expenses, excluding fuel, electricity sales and gas purchase derivative settlement (gains) losses.
(4) Total energy operating expenses equals fuel and gas purchase derivative settlement (gains) losses less electricity sales.
PRODUCTION STATISTICS
Three Months Ended |
|||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||
Net Oil, Natural Gas and NGLs Production Per Day (1) : |
|||||
Oil (mbbl/d) |
|||||
| California (2) |
21.0 | 22.2 | 21.7 | ||
| Utah | 3.0 | 2.2 | 2.3 | ||
| Colorado (3) |
— | — | — | ||
| Total oil | 24.0 | 24.4 | 24.0 | ||
Natural gas (mmcf/d) |
|||||
| California (2) |
— | — | — | ||
| Utah | 11.0 | 9.2 | 10.3 | ||
| Colorado (3) |
— | 2.3 | 7.2 | ||
| Total natural gas | 11.0 | 11.5 | 17.5 | ||
NGLs (mbbl/d) |
|||||
| California (2) |
— | — | — | ||
| Utah | 0.4 | 0.4 | 0.4 | ||
| Colorado (3) |
— | — | — | ||
| Total NGLs | 0.4 | 0.4 | 0.4 | ||
Total Production (mboe/d) (4) |
26.2 | 26.7 | 27.3 | ||
__________
(1) Production represents volumes sold during the period. We also consume a portion of the natural gas we produce on lease to extract oil and gas.
(2) Our Placerita properties, in the Ventura basin, were divested in October 2021.
(3) Our properties in Colorado were in the Piceance basin, all of which were all divested in January 2022.
(4) Natural gas volumes have been converted to boe based on energy content of six mcf of gas to one bbl of oil. Barrels of oil equivalence does not necessarily result in price equivalence. The price of natural gas on a barrel of oil equivalent basis is currently substantially lower than the corresponding price for oil and has been similarly lower for a number of years. For example, in the three months ended June 30, 2022, the average prices of Brent oil and Henry Hub natural gas were $111.98 per bbl and $7.50 per mmbtu respectively.
CAPITAL EXPENDITURES (ACCRUAL BASIS)
Three Months Ended |
||||||||
June 30, 2022 (2) |
March 31, 2022 (2) |
June 30, 2021 |
||||||
(in thousands) |
||||||||
| Capital expenditures (accrual basis) (1) |
$ | 34,086 | $ | 27,620 | $ | 43,461 | ||
__________
(1) Capital expenditures on an accrual basis include capitalized overhead and interest and excludes acquisitions and asset retirement spending.
(2) Capital expenditures in the quarter ended June 30, 2022 and March 31, 2022 included approximately $1 million each period for C&J Well Services which was acquired on October 1, 2021.
NON-GAAP FINANCIAL MEASURES AND RECONCILIATIONS
Adjusted Net Income (Loss) is not a measure of net income (loss) and Discretionary Free Cash Flow is not a measure of cash flow, and Adjusted EBITDA and Adjusted EBITDA Unhedged are not measures of either, in all cases, as determined by GAAP. Adjusted EBITDA, Adjusted EBITDA Unhedged, Adjusted Net Income (Loss) and Discretionary Free Cash Flow are supplemental non-GAAP financial measures used by management and external users of our financial statements, such as industry analysts, investors, lenders and rating agencies. We define Adjusted Net Income (Loss) as net income (loss) adjusted for derivative gains or losses net of cash received or paid for scheduled derivative settlements, other unusual and infrequent items, and the income tax expense or benefit of these adjustments using our effective tax rate. We define Adjusted EBITDA as earnings before interest expense; income taxes; depreciation, depletion, and amortization; derivative gains or losses net of cash received or paid for scheduled derivative settlements; impairments; stock compensation expense; and unusual and infrequent items. We define Discretionary Free Cash Flow as cash flow from operations less regular fixed dividends and the capital needed to hold production flat.
Adjusted Net Income (Loss) excludes the impact of unusual and infrequent items affecting earnings that vary widely and unpredictably, including non-cash items such as derivative gains and losses. This measure is used by management when comparing results period over period. Our management believes Adjusted EBITDA provides useful information in assessing our financial condition, results of operations and cash flows and is widely used by the industry and the investment community. The measure also allows our management to more effectively evaluate our operating performance and compare the results between periods without regard to our financing methods or capital structure. We also use Adjusted EBITDA in planning our capital allocation to sustain production levels and to determine our strategic hedging needs aside from the hedging requirements of the 2021 RBL Facility. Management believes Discretionary Free Cash Flow provides useful information in assessing our financial condition, and is the primary metric to determine the quarterly variable dividend. We expect to allocate 60% of Discretionary Free Cash Flow predominantly in the form of cash variable dividends, as well as opportunistic debt repurchases. The remaining 40% will be used for opportunistic growth, including from our extensive inventory of drilling opportunities, advancing our short- and long-term sustainability initiatives, share repurchases, and/or capital retention. Our management believes Discretionary Free Cash Flow provides useful information in assessing our financial condition, and is the primary metric to determine the quarterly variable dividend.
Adjusted General and Administrative Expenses 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. We define Adjusted General and Administrative Expenses as general and administrative expenses adjusted for non-cash stock compensation expense and unusual and infrequent costs. Management believes Adjusted General and Administrative Expenses is useful because it allows us to more effectively compare our performance from period to period. We exclude the items listed above from general and administrative expenses in arriving at Adjusted General and Administrative Expenses because these amounts can vary widely and unpredictably in nature, timing, amount and frequency and stock compensation expense is non-cash in nature.
While Adjusted Net Income (Loss), Adjusted EBITDA, Adjusted EBITDA Unhedged, Adjusted General and Administrative Expenses and Discretionary Free Cash Flow are non-GAAP measures, the amounts included in the calculations of Adjusted Net Income (Loss), Adjusted EBITDA, Adjusted EBITDA Unhedged, Adjusted General and Administrative Expenses and Discretionary Free Cash Flow were computed in accordance with GAAP. These measures are provided in addition to, and not as an alternative for, income and liquidity measures calculated in accordance with GAAP and should not be considered as an alternative to, or more meaningful than, income and liquidity measures calculated in accordance with GAAP. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing our financial performance, such as our cost of capital and tax structure, as well as the historic cost of depreciable and depletable assets. Our computations of Adjusted Net Income (Loss), Adjusted EBITDA, Adjusted EBITDA Unhedged, Adjusted General and Administrative Expenses and Discretionary Free Cash Flow may not be comparable to other similarly titled measures used by other companies. Adjusted Net Income (Loss), Adjusted EBITDA, Adjusted EBITDA Unhedged, Adjusted General and Administrative Expenses and Discretionary Free Cash Flow should be read in conjunction with the information contained in our financial statements prepared in accordance with GAAP.
ADJUSTED NET INCOME (LOSS)
The following table presents a reconciliation of the GAAP financial measure of net income (loss) to the non-GAAP financial measure of Adjusted Net Income (Loss).
Three Months Ended |
|||||||||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||||||||
($ thousands, except per share amounts) |
|||||||||||
| Net income (loss) | $ | 43,354 | $ | (56,810 | ) | $ | (12,881 | ) | |||
| Add (Subtract): | |||||||||||
| Losses on derivatives | 51,319 | 132,804 | 44,014 | ||||||||
| Net cash paid for scheduled derivative settlements | (37,628 | ) | (32,152 | ) | (37,431 | ) | |||||
| Other operating expenses | 353 | 3,769 | 42 | ||||||||
| Non-recurring costs | — | 198 | — | ||||||||
| Total additions, net | 14,044 | 104,619 | 6,625 | ||||||||
| Income tax expense of adjustments and discrete income tax items | (4,262 | ) | (4,938 | ) | (37 | ) | |||||
| Adjusted Net Income (Loss) | $ | 53,136 | $ | 42,871 | $ | (6,293 | ) | ||||
| Basic EPS on Adjusted Net Income (Loss) | $ | 0.67 | $ | 0.53 | $ | (0.08 | ) | ||||
| Diluted EPS on Adjusted Net Income (Loss) | $ | 0.64 | $ | 0.51 | $ | (0.08 | ) | ||||
| Weighted average shares of common stock outstanding – basic | 79,596 | 80,298 | 80,471 | ||||||||
| Weighted average shares of common stock outstanding – diluted | 83,015 | 84,447 | 80,471 | ||||||||
ADJUSTED EBITDA AND ADJUSTED EBITDA UNHEDGED
The following tables present a reconciliation of the GAAP financial measures of net income (loss) and net cash provided by operating activities to the non-GAAP financial measures of Adjusted EBITDA and Adjusted EBITDA Unhedged.
Three Months Ended |
|||||||||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||||||||
($ thousands) |
|||||||||||
| Net income (loss) | $ | 43,354 | $ | (56,810 | ) | $ | (12,881 | ) | |||
| Add (Subtract): | |||||||||||
| Interest expense | 7,729 | 7,675 | 8,217 | ||||||||
| Income tax expense (benefit) | 2,145 | (3,351 | ) | (72 | ) | ||||||
| Depreciation, depletion and amortization | 38,055 | 39,777 | 35,850 | ||||||||
| Losses on derivatives | 51,319 | 132,804 | 44,014 | ||||||||
| Net cash paid for scheduled derivative settlements | (37,628 | ) | (32,152 | ) | (37,431 | ) | |||||
| Other operating expense | 353 | 3,769 | 42 | ||||||||
| Stock compensation expense | 4,420 | 3,802 | 2,860 | ||||||||
| Non-recurring costs (1) |
— | 198 | — | ||||||||
| Adjusted EBITDA | $ | 109,747 | $ | 95,712 | $ | 40,599 | |||||
| Net cash paid for scheduled derivative settlements | 37,628 | 32,152 | 37,431 | ||||||||
| Adjusted EBITDA Unhedged | $ | 147,375 | $ | 127,864 | $ | 78,030 | |||||
| Net cash provided by operating activities | $ | 111,242 | $ | 48,530 | $ | 21,429 | |||||
| Add (Subtract): | |||||||||||
| Cash interest payments | 449 | 14,539 | 288 | ||||||||
| Cash income tax payments | 2,484 | — | — | ||||||||
| Non-recurring costs (1) |
— | 198 | — | ||||||||
| Other changes in operating assets and liabilities | (4,428 | ) | 32,445 | 18,882 | |||||||
| Adjusted EBITDA | $ | 109,747 | $ | 95,712 | $ | 40,599 | |||||
| Net cash paid for scheduled derivative settlements | 37,628 | 32,152 | 37,431 | ||||||||
| Adjusted EBITDA Unhedged | $ | 147,375 | $ | 127,864 | $ | 78,030 | |||||
__________
(1) Non-recurring costs include legal and professional service expenses related to acquisition and divestiture activity.
Adjusted EBITDA is the measure reported to the chief operating decision maker (CODM) for purposes of making decisions about allocating resources to and assessing performance of each segment. EBITDA represents earnings before interest expense; income taxes; depreciation, depletion, and amortization; derivative gains or losses net of cash received or paid for scheduled derivative settlements; impairments; stock compensation expense; and unusual and infrequent items.
Three Months Ended June 30, 2022 |
|||||||||||||||
Development & Production |
Well Servicing and Abandonment |
Corporate/Eliminations |
Consolidated Company |
||||||||||||
(in thousands) |
|||||||||||||||
Adjusted EBITDA reconciliation to net income (loss): |
|||||||||||||||
| Net income (loss) | $ | 68,885 | $ | 3,307 | $ | (28,838 | ) | $ | 43,354 | ||||||
Add (Subtract): |
|||||||||||||||
| Interest expense | — | — | 7,729 | 7,729 | |||||||||||
| Income tax benefit | — | — | 2,145 | 2,145 | |||||||||||
| Depreciation, depletion, and amortization | 33,956 | 3,017 | 1,082 | 38,055 | |||||||||||
| Losses on derivatives | 51,319 | — | — | 51,319 | |||||||||||
| Net cash paid for scheduled derivative settlements | (37,628 | ) | — | — | (37,628 | ) | |||||||||
| Other operating expenses | 30 | (210 | ) | 533 | 353 | ||||||||||
| Stock compensation expense | 380 | 86 | 3,954 | 4,420 | |||||||||||
Adjusted EBITDA |
$ | 116,942 | $ | 6,200 | $ | (13,395 | ) | $ | 109,747 | ||||||
Three Months Ended Mar 31, 2022 |
|||||||||||||||
Development & Production |
Well Servicing and Abandonment |
Corporate/Eliminations |
Consolidated Company |
||||||||||||
(in thousands) |
|||||||||||||||
Adjusted EBITDA reconciliation to net income (loss): |
|||||||||||||||
| Net loss | $ | (34,291 | ) | $ | (284 | ) | $ | (22,235 | ) | $ | (56,810 | ) | |||
Add (Subtract): |
|||||||||||||||
| Interest expense | — | — | 7,675 | 7,675 | |||||||||||
| Income tax expense | — | — | (3,351 | ) | (3,351 | ) | |||||||||
| Depreciation, depletion, and amortization | 35,474 | 3,179 | 1,124 | 39,777 | |||||||||||
| Losses on derivatives | 132,804 | — | — | 132,804 | |||||||||||
| Net cash paid for scheduled derivative settlements | (32,152 | ) | — | — | (32,152 | ) | |||||||||
| Other operating income | 3,495 | 174 | 100 | 3,769 | |||||||||||
| Stock compensation expense | 319 | 33 | 3,450 | 3,802 | |||||||||||
| Non-recurring costs | — | 198 | — | 198 | |||||||||||
Adjusted EBITDA |
$ | 105,649 | $ | 3,300 | $ | (13,237 | ) | $ | 95,712 | ||||||
ADJUSTED GENERAL AND ADMINISTRATIVE EXPENSES
The following table presents a reconciliation of the GAAP financial measure of general and administrative expenses to the non-GAAP financial measure of Adjusted General and Administrative Expenses.
Three Months Ended |
|||||||||||
June 30, 2022 |
March 31, 2022 |
June 30, 2021 |
|||||||||
($ in thousands except per mboe amounts) |
|||||||||||
| General and administrative expenses | $ | 23,183 | $ | 22,942 | $ | 16,065 | |||||
| Subtract: | |||||||||||
| Non-cash stock compensation expense (G&A portion) | (4,263 | ) | (3,706 | ) | (2,763 | ) | |||||
| Non-recurring costs | — | (198 | ) | — | |||||||
| Adjusted General and Administrative Expenses | $ | 18,920 | $ | 19,038 | $ | 13,302 | |||||
| Well servicing and abandonment segment | $ | 3,285 | $ | 3,070 | $ | — | |||||
| Development and production segment, and corporate | $ | 15,635 | $ | 15,968 | $ | 13,302 | |||||
| Development and production segment, and corporate ($/boe) | $ | 6.55 | $ | 6.64 | $ | 5.35 | |||||
| Total mboe | 2,386 | 2,406 | 2,485 | ||||||||
DISCRETIONARY FREE CASH FLOW
The following table presents a reconciliation of the non-GAAP financial measure Discretionary Free Cash Flow to the GAAP financial measure of operating cash flow for each of the periods indicated.
Three Months Ended |
Three Months Ended |
|||||
June 30. 2022 |
March 31, 2022 |
|||||
(in thousands) |
||||||
Discretionary Free Cash Flow: |
||||||
| Operating cash flow (1) |
$ | 111,242 | $ | 48,530 | ||
Subtract: |
||||||
| Maintenance capital (2)(3) |
(32,134 | ) | (26,437 | ) | ||
| Fixed dividends (4) |
(4,726 | ) | (5,236 | ) | ||
Discretionary Free Cash Flow |
$ | 74,382 | $ | 16,857 | ||
__________
(1) On a consolidated basis.
(2) D&P business only.
(3) Maintenance capital is the capital required to keep annual production flat, calculated as the capital expenditures for the D&P business during the period presented.
(4) Represents fixed dividends declared which are included in the “Dividends declared on common stock” line in the the consolidated statement of stockholders’ equity.
Contact Contact: Berry Corporation (bry) Todd Crabtree - Director, Investor Relations (661) 616-3811 [email protected]
