Quarterly Highlights
- Generated Adjusted EBITDA(1) of
$69 million and Adjusted Free Cash Flow(1) of$34 million - Delivered strong operational results, with a nearly 7% increase in production over first quarter 2023
- Repurchased more than 1.4 million shares of common stock at an average price of
$7.04 per share - Declared total dividends of
$0.14 per share - Signed agreement to acquire
Kern County producerMacpherson Energy Corporation for$70 million funded partially through capital reallocation
__________
(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.
“In the second quarter we successfully executed on our strategy to deliver meaningful returns,” said
“We are excited about our pending acquisition of
Second Quarter 2023 Results
Net income was
The Company's average daily production increased in the second quarter 2023 to 25,900 boe/d compared to 24,300 boe/d in the first quarter 2023. Company-wide oil production in the second quarter 2023 was 24,000 bbl/d, accounting for 93% of total Company production, with
Company-wide realized oil price, including hedging effects, was
Lease operating expenses, which includes fuel gas costs for
Taxes, other than income taxes, increased 22%, in the second quarter 2023 compared to the first quarter 2023 due to higher mark-to-market prices for greenhouse gas (“GHG”) allowances in the second quarter.
General and administrative expenses decreased 29% in the second quarter 2023 compared to the first quarter 2023, in large part due to non-recurring executive transition and workforce reduction costs that occurred in the first quarter 2023. Adjusted General and Administrative Expenses(1), which excludes non-cash stock compensation costs and nonrecurring costs, decreased 3% in the second quarter 2023 compared to the first quarter 2023, as a result of the cost savings initiatives that began in early 2023.
The income for the well servicing and abandonment business,
For the second quarter 2023, capital expenditures were approximately
At
“We increased Adjusted EBITDA for the second quarter by 17% over the first quarter and generated solid Adjusted Free Cash Flow of
2023 Outlook
We currently anticipate that our full-year results will be in line with previous guidance, before consideration of the Macpherson transaction, except with respect to capital expenditures. We expect 2023 capital expenditures for both Berry and
Quarterly Dividends
The Company’s Board of Directors declared dividends totaling
Earnings Conference Call
The Company will host a conference call to discuss these results:
Call Date: Call Time: | |
Join the live listen-only audio webcast at https://edge.media-server.com/mmc/p/yrmp93rj or at https://bry.com/category/events | |
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/BI1dce5edf8c144895becc0633be60f1dc
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/yrmp93rj or
https://bry.com/category/events
About
Berry is a publicly traded (NASDAQ: BRY) western
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 our financial position; liquidity; cash flows (including, but not limited to, Adjusted Free Cash Flow); financial and operating results; capital program and development and production plans; operations and business strategy; projected G&A savings from workforce reductions; potential acquisition and other strategic opportunities; reserves; hedging activities; capital expenditures; return of capital; our shareholder return model and the payment of future dividends; future repurchases of stock or debt; capital investments; our ESG strategy and initiation of new projects or business in connection therewith; recovery factors; consummation of the acquisition and the timing thereof; projected accretion to financial and production results; projected synergies related to the acquisition; anticipated increases to free cash flow and shareholder returns; our capital expenditures and leverage profile; 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 financial position, financial and operating results, liquidity, cash flows (including, but not limited to, Adjusted Free Cash Flow) and business prospects.
Berry cautions you that these forward-looking statements are subject to all of the risks and uncertainties incident to acquisition transactions and 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
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 responsibility 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
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 | ||||||||||||
(unaudited) ($ and shares in thousands, except per share amounts) | ||||||||||||
Consolidated Statement of Operations Data: | ||||||||||||
Revenues and other: | ||||||||||||
Oil, natural gas and natural gas liquids sales | $ | 157,703 | $ | 166,357 | $ | 240,071 | ||||||
Service revenue | 47,674 | 44,623 | 46,178 | |||||||||
Electricity sales | 3,078 | 5,445 | 7,419 | |||||||||
Gains (losses) on oil and gas sales derivatives | 20,871 | 38,499 | (40,658 | ) | ||||||||
Other revenues | 36 | 45 | 120 | |||||||||
Total revenues and other | 229,362 | 254,969 | 253,130 | |||||||||
Expenses and other: | ||||||||||||
Lease operating expenses | 54,707 | 134,835 | 72,455 | |||||||||
Cost of services | 37,083 | 36,099 | 36,709 | |||||||||
Electricity generation expenses | 1,273 | 2,500 | 6,122 | |||||||||
Transportation expenses | 1,096 | 1,041 | 1,108 | |||||||||
Acquisition costs | 972 | — | — | |||||||||
General and administrative expenses | 22,488 | 31,669 | 23,183 | |||||||||
Depreciation, depletion and amortization | 39,755 | 40,121 | 38,055 | |||||||||
Taxes, other than income taxes | 13,707 | 10,460 | 11,214 | |||||||||
Losses (gains) on natural gas purchase derivatives | 14,024 | (610 | ) | 10,661 | ||||||||
Other operating (income) expenses | (1,033 | ) | (286 | ) | 353 | |||||||
Total expenses and other | 184,072 | 255,829 | 199,860 | |||||||||
Other (expenses) income: | ||||||||||||
Interest expense | (8,794 | ) | (7,837 | ) | (7,729 | ) | ||||||
Other, net | (110 | ) | (75 | ) | (42 | ) | ||||||
Total other (expenses) income | (8,904 | ) | (7,912 | ) | (7,771 | ) | ||||||
Income (loss) before income taxes | 36,386 | (8,772 | ) | 45,499 | ||||||||
Income tax expense (benefit) | 10,616 | (2,913 | ) | 2,145 | ||||||||
Net income (loss) | $ | 25,770 | $ | (5,859 | ) | $ | 43,354 | |||||
Net income (loss) per share: | ||||||||||||
Basic | $ | 0.34 | $ | (0.08 | ) | $ | 0.54 | |||||
Diluted | $ | 0.33 | $ | (0.08 | ) | $ | 0.52 | |||||
Weighted-average shares of common stock outstanding - basic | 76,721 | 76,112 | 79,596 | |||||||||
Weighted-average shares of common stock outstanding - diluted | 79,285 | 76,112 | 83,015 | |||||||||
Adjusted Net Income(1) | $ | 11,666 | $ | 5,307 | $ | 53,591 | ||||||
Weighted-average shares of common stock outstanding - diluted | 79,285 | 79,210 | 83,015 | |||||||||
Diluted earnings per share on Adjusted Net Income(1) | $ | 0.15 | $ | 0.07 | $ | 0.65 | ||||||
Three Months Ended | ||||||||||||
(unaudited) ($ and shares in thousands, except per share amounts) | ||||||||||||
Adjusted EBITDA(1) | $ | 69,055 | $ | 59,337 | $ | 109,747 | ||||||
Adjusted Free Cash Flow(1) | $ | 33,774 | $ | (26,681 | ) | $ | 74,382 | |||||
Adjusted General and Administrative Expenses(1) | $ | 19,109 | $ | 19,737 | $ | 18,920 | ||||||
Effective Tax Rate | 29 | % | 33 | % | 5 | % | ||||||
Cash Flow Data: | ||||||||||||
Net cash provided by operating activities | $ | 62,538 | $ | 1,781 | $ | 111,242 | ||||||
Net cash used in investing activities | $ | (27,961 | ) | $ | (30,460 | ) | $ | (38,863 | ) | |||
Net cash used in financing activities | $ | (40,128 | ) | $ | (3,454 | ) | $ | (37,844 | ) |
__________
(1) See further discussion and reconciliation in “Non-GAAP Financial Measures and Reconciliations”.
(unaudited) ($ and shares in thousands) | ||||||||
Balance Sheet Data: | ||||||||
Total current assets | $ | 134,431 | $ | 218,055 | ||||
Total property, plant and equipment, net | $ | 1,335,572 | $ | 1,359,813 | ||||
Total current liabilities | $ | 148,127 | $ | 234,207 | ||||
Long-term debt | $ | 421,347 | $ | 395,735 | ||||
Total stockholders' equity | $ | 760,575 | $ | 800,485 | ||||
Outstanding common stock shares as of | 75,661 | 75,768 | ||||||
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.
Three Months Ended | ||||||||||||||||
E&P | Well Servicing and Abandonment | Corporate/ Eliminations | ||||||||||||||
(unaudited) (in thousands) | ||||||||||||||||
Revenues(1) | $ | 160,817 | $ | 49,299 | $ | (1,625 | ) | $ | 208,491 | |||||||
Net income (loss) before income taxes | $ | 62,012 | $ | 4,836 | $ | (30,462 | ) | $ | 36,386 | |||||||
Adjusted EBITDA(2) | $ | 78,274 | $ | 7,689 | $ | (16,908 | ) | $ | 69,055 | |||||||
Capital expenditures | $ | 19,625 | $ | 1,334 | $ | 936 | $ | 21,895 | ||||||||
Total assets | $ | 1,457,694 | $ | 72,653 | $ | (8,644 | ) | $ | 1,521,703 |
Three Months Ended | ||||||||||||||||
E&P | Well Servicing and Abandonment | Corporate/ Eliminations | ||||||||||||||
(unaudited) (in thousands) | ||||||||||||||||
Revenues(1) | $ | 171,847 | $ | 46,363 | $ | (1,740 | ) | $ | 216,470 | |||||||
Net income (loss) before income taxes | $ | 24,170 | $ | 2,114 | $ | (35,056 | ) | $ | (8,772 | ) | ||||||
Adjusted EBITDA(2) | $ | 75,797 | $ | 5,438 | $ | (21,898 | ) | $ | 59,337 | |||||||
Capital expenditures | $ | 19,272 | $ | 982 | $ | 379 | $ | 20,633 | ||||||||
Total assets | $ | 1,471,679 | $ | 80,897 | $ | (12,335 | ) | $ | 1,540,241 |
Three Months Ended | ||||||||||||||||
E&P | Well Servicing and Abandonment | Corporate/ Eliminations | ||||||||||||||
(unaudited) (in thousands) | ||||||||||||||||
Revenues(1) | $ | 247,610 | $ | 46,178 | $ | — | $ | 293,788 | ||||||||
Net income (loss) before income taxes | $ | 68,885 | $ | 3,307 | $ | (26,693 | ) | $ | 45,499 | |||||||
Adjusted EBITDA(2) | $ | 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 |
__________
(1) These revenues do not include hedge settlements.
(2) See further discussion and reconciliation in “Non-GAAP Financial Measures and Reconciliations”.
COMMODITY PRICING
Three Months Ended | ||||||||||||
Weighted Average Realized Prices | ||||||||||||
Oil without hedge ($/bbl) | $ | 70.68 | $ | 74.69 | $ | 105.70 | ||||||
Effects of scheduled derivative settlements ($/bbl) | $ | (0.81 | ) | $ | (3.65 | ) | $ | (21.92 | ) | |||
Oil with hedge ($/bbl) | $ | 69.87 | $ | 71.04 | $ | 83.78 | ||||||
Natural gas ($/mcf) | $ | 2.87 | $ | 17.39 | $ | 7.35 | ||||||
NGLs ($/bbl) | $ | 22.16 | $ | 34.10 | $ | 56.47 | ||||||
Index Prices | ||||||||||||
Brent oil ($/bbl) | $ | 77.73 | $ | 82.16 | $ | 111.98 | ||||||
WTI oil ($/bbl) | $ | 73.73 | $ | 76.15 | $ | 108.71 | ||||||
Natural gas ($/mmbtu) – | $ | 5.66 | $ | 24.81 | $ | 7.53 | ||||||
Natural gas ($/mmbtu) – Northwest, | $ | 2.85 | $ | 22.36 | $ | 6.69 | ||||||
$ | 2.16 | $ | 2.64 | $ | 7.50 |
__________
(1) The natural gas we purchase to generate steam and electricity is primarily based on Rockies price indexes, including transportation charges, as we currently purchase a substantial majority of gas needs from the Rockies, with the balance purchased in
(2) Northwest,
Natural gas prices and differentials are strongly affected by local market fundamentals, availability of transportation capacity from producing areas and seasonal impacts. The Company's key exposure to gas prices is in costs. The Company purchases substantially more natural gas for
CURRENT HEDGING SUMMARY
As of
Q3 2023 | Q4 2023 | FY 2024 | FY 2025 | FY 2026 | ||||||||||||||||
Brent – Crude Oil production | ||||||||||||||||||||
Swaps | ||||||||||||||||||||
Hedged volume (bbls) | 1,272,717 | 1,288,000 | 4,146,817 | 752,125 | 487,268 | |||||||||||||||
Weighted-average price ($/bbl) | $ | 76.54 | $ | 76.60 | $ | 76.13 | $ | 70.89 | $ | 68.71 | ||||||||||
Sold Calls(1) | ||||||||||||||||||||
Hedged volume (bbls) | 368,000 | 368,000 | 732,000 | 2,486,127 | 472,500 | |||||||||||||||
Weighted-average price ($/bbl) | $ | 106.00 | $ | 106.00 | $ | 105.00 | $ | 91.11 | $ | 82.21 | ||||||||||
Purchased Puts (net)(2) | ||||||||||||||||||||
Hedged volume (bbls) | 552,000 | 552,000 | 1,281,000 | 2,486,127 | 472,500 | |||||||||||||||
Weighted-average price ($/bbl) | $ | 50.00 | $ | 50.00 | $ | 50.00 | $ | 58.53 | $ | 60.00 | ||||||||||
Sold Puts (net)(2) | ||||||||||||||||||||
Hedged volume (bbls) | 184,000 | 154,116 | 183,000 | — | — | |||||||||||||||
Weighted-average price ($/bbl) | $ | 40.00 | $ | 40.00 | $ | 40.00 | $ | — | $ | — | ||||||||||
NWPL - Natural Gas purchases | ||||||||||||||||||||
Swaps | ||||||||||||||||||||
Hedged volume (mmbtu) | 3,680,000 | 3,680,000 | 10,980,000 | 6,080,000 | — | |||||||||||||||
Weighted-average price ($/mmbtu) | $ | 5.34 | $ | 5.34 | $ | 4.21 | $ | 4.27 | $ | — | ||||||||||
Gas Basis Differentials | ||||||||||||||||||||
NWPL/HH – Natural Gas Purchases | ||||||||||||||||||||
Hedged volume (mmbtu) | — | 610,000 | — | — | — | |||||||||||||||
Weighted-average price ($/mmbtu) | $ | — | $ | 1.12 | $ | — | $ | — | $ | — |
__________
(1) Purchased calls and sold calls with the same strike price have been presented on a net basis.
(2) Purchased puts and sold puts with the same strike price have been presented on a net basis.
E&P FIELD OPERATIONS
Three Months Ended | ||||||||||||
(unaudited) ($ in per boe amounts) | ||||||||||||
Expenses from field operations | ||||||||||||
Lease operating expenses | $ | 23.17 | $ | 61.65 | $ | 30.37 | ||||||
Electricity generation expenses | 0.54 | 1.14 | 2.57 | |||||||||
Transportation expenses | 0.46 | 0.48 | 0.46 | |||||||||
Total | $ | 24.17 | $ | 63.27 | $ | 33.40 | ||||||
Cash settlements paid (received) for gas purchase hedges | $ | 4.56 | $ | (25.11 | ) | $ | (4.27 | ) | ||||
E&P non-production revenues | ||||||||||||
Electricity sales | $ | 1.30 | $ | 2.49 | $ | 3.11 | ||||||
Transportation sales | 0.02 | 0.02 | 0.05 | |||||||||
Total | $ | 1.32 | $ | 2.51 | $ | 3.16 | ||||||
Overall, management assesses the efficiency of the Company's E&P field operations by considering core E&P operating expenses together with cogeneration, marketing and transportation activities. In particular, a core component of E&P operations in
Lease operating expenses include fuel, labor, field office, vehicle, supervision, maintenance, tools and supplies, and workover expenses. Electricity generation expenses include the portion of fuel, labor, maintenance, and tools and supplies from two of the Company's cogeneration facilities allocated to electricity generation expense; the remaining cogeneration expenses are included in lease operating expense. Transportation expenses relate to costs to transport the oil and gas that is produced within the Company's properties or moved to the market. Marketing expenses mainly relate to natural gas purchased from third parties that moves through gathering and processing systems and then is sold to third parties. Electricity revenue is from the sale of excess electricity from two of the Company's cogeneration facilities to a
PRODUCTION STATISTICS
Three Months Ended | |||||||||
Net Oil, Natural Gas and NGLs Production Per Day(1): | |||||||||
Oil (mbbl/d) | |||||||||
20.8 | 19.9 | 21.0 | |||||||
3.2 | 2.7 | 3.0 | |||||||
Total oil | 24.0 | 22.6 | 24.0 | ||||||
Natural gas (mmcf/d) | |||||||||
— | — | — | |||||||
9.2 | 8.7 | 11.0 | |||||||
Total natural gas | 9.2 | 8.7 | 11.0 | ||||||
NGLs (mbbl/d) | |||||||||
— | — | — | |||||||
0.4 | 0.2 | 0.4 | |||||||
Total NGLs | 0.4 | 0.2 | 0.4 | ||||||
Total Production (mboe/d)(2) | 25.9 | 24.3 | 26.2 |
__________
(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) 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
(3) Includes production for
CAPITAL EXPENDITURES
Three Months Ended | ||||||||||||
(unaudited) (in thousands) | ||||||||||||
Capital expenditures(1)(2) | $ | 21,895 | $ | 20,633 | $ | 34,086 |
__________
(1) Capital expenditures include capitalized overhead and interest and excludes acquisitions and asset retirement spending.
(2) Capital expenditures in the three months ended
NON-GAAP FINANCIAL MEASURES AND RECONCILIATIONS
Adjusted Net Income (Loss) is not a measure of net income (loss), Adjusted Free Cash Flow is not a measure of cash flow, and Adjusted EBITDA is not a measure of either net income (loss) or cash flow, in all cases, as determined by GAAP. Adjusted EBITDA, Adjusted Free Cash Flow, Adjusted Net Income (Loss) and Adjusted General and Administrative Expenses 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 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. 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.
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, unusual and infrequent items, and the income tax expense or benefit of these adjustments using our statutory tax rate. 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. We believe Adjusted Net Income (Loss) is useful to investors because it reflects how management evaluates the Company’s ongoing financial and operating performance from period-to-period after removing certain transactions and activities that affect comparability of the metrics and are not reflective of the Company’s core operations. We believe this also makes it easier for investors to compare our period-to-period results with our peers.
We define Adjusted Free Cash Flow, which is a non-GAAP financial measure, as cash flow from operations less regular fixed dividends and maintenance capital. Maintenance capital represents the capital expenditures needed to maintain substantially the same volume of annual oil and gas production and is defined as capital expenditures, excluding, when applicable, E&P capital expenditures that are related to strategic business expansion, such as acquisitions of oil and gas properties and any exploration and development activities to increase production beyond the prior year’s annual production volumes and capital expenditures in our well servicing and abandonment and corporate segments that are related to ancillary sustainability initiatives or other expenditures that are discretionary and unrelated to maintenance of our core business. Management believes Adjusted Free Cash Flow may be useful in an investor analysis of our ability to generate cash from operating activities from our existing oil and gas asset base after maintaining the existing production volumes of that asset base to return capital to stockholders, fund further business expansion through acquisitions or investments in our existing asset base to increase production volumes and pay other non-discretionary expenses. Management also uses Adjusted Free Cash Flow as the primary metric to determine the quarterly variable dividend. In early 2023, we updated our shareholder return model, including to double our quarterly fixed dividend to
Adjusted Free Cash Flow does not represent the total increase or decrease in our cash balance, and it should not be inferred that the entire amount of Adjusted Free Cash Flow is available for variable dividends, debt or share repurchases, strategic acquisitions or other discretionary expenditures, since we have mandatory debt service requirements and other non-discretionary expenditures that are not deducted from this measure.
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 believe Adjusted General and Administrative Expenses is useful to investors because it reflects how management evaluates the Company’s ongoing general and administrative expenses from period-to-period after removing non-cash stock compensation, as well as unusual or infrequent costs that affect comparability of the metrics and are not reflective of the Company’s administrative costs. We believe this also makes it easier for investors to compare our period-to-period results with our peers.
While Adjusted EBITDA, Adjusted Free Cash Flow, Adjusted Net Income (Loss) and Adjusted General and Administrative Expenses are non-GAAP measures, the amounts included in the calculation of Adjusted EBITDA, Adjusted Free Cash Flow, Adjusted Net Income (Loss) and Adjusted General and Administrative Expenses 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 EBITDA, Adjusted Free Cash Flow, Adjusted Net Income (Loss) and Adjusted General and Administrative Expenses may not be comparable to other similarly titled measures used by other companies. Adjusted EBITDA, Adjusted Free Cash Flow, Adjusted Net Income (Loss) and Adjusted General and Administrative Expenses should be read in conjunction with the information contained in our financial statements prepared in accordance with GAAP.
ADJUSTED EBITDA
The following tables present a reconciliation of the non-GAAP financial measure Adjusted EBITDA to the GAAP financial measures of net income (loss) and net cash provided (or used) by operating activities, as applicable, for each of the periods indicated.
Three Months Ended | ||||||||||||
(unaudited) (in thousands) | ||||||||||||
Adjusted EBITDA reconciliation to net income (loss) and net cash provided by operating activities: | ||||||||||||
Net income (loss) | $ | 25,770 | $ | (5,859 | ) | $ | 43,354 | |||||
Add (Subtract): | ||||||||||||
Interest expense | 8,794 | 7,837 | 7,729 | |||||||||
Income tax expense (benefit) | 10,616 | (2,913 | ) | 2,145 | ||||||||
Depreciation, depletion, and amortization | 39,755 | 40,121 | 38,055 | |||||||||
(Gains) losses on derivatives | (6,847 | ) | (39,109 | ) | 51,319 | |||||||
Net cash (paid) received for scheduled derivative settlements | (12,524 | ) | 47,467 | (37,628 | ) | |||||||
Other operating (income) expenses | (1,033 | ) | (286 | ) | 353 | |||||||
Stock compensation expense | 3,552 | 4,766 | 4,420 | |||||||||
Acquisition costs(1) | 972 | — | — | |||||||||
Non-recurring costs(2) | — | 7,313 | — | |||||||||
Adjusted EBITDA | $ | 69,055 | $ | 59,337 | $ | 109,747 | ||||||
Net cash provided by operating activities | $ | 62,538 | $ | 1,781 | $ | 111,242 | ||||||
Add (Subtract): | ||||||||||||
Cash interest payments | 1,004 | 14,388 | 449 | |||||||||
Cash income tax payments | 670 | — | 2,484 | |||||||||
Non-recurring costs(2) | — | 7,313 | — | |||||||||
Changes in operating assets and liabilities – working capital(3) | 6,065 | 36,745 | (4,058 | ) | ||||||||
Other operating (income) expenses – cash portion(4) | (1,222 | ) | (890 | ) | (370 | ) | ||||||
Adjusted EBITDA | $ | 69,055 | $ | 59,337 | $ | 109,747 |
__________
(1) Includes costs related to the acquisition of
(2) Non-recurring costs included executive transition costs and workforce reduction costs in the first quarter of 2023.
(3) Changes in other assets and liabilities consists of working capital and various immaterial items.
(4) Represents the cash portion of other operating (income) expenses from the income statement, net of the non-cash portion in the cash flow statement.
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 | ||||||||||||||||
E&P | Well Servicing and Abandonment | Corporate/ Eliminations | ||||||||||||||
(unaudited) (in thousands) | ||||||||||||||||
Adjusted EBITDA reconciliation to net income (loss): | ||||||||||||||||
Net income (loss) | $ | 62,012 | $ | 4,836 | $ | (41,078 | ) | $ | 25,770 | |||||||
Add (Subtract): | ||||||||||||||||
Interest (income) expense | — | (28 | ) | 8,822 | 8,794 | |||||||||||
Income tax expense | — | — | 10,616 | 10,616 | ||||||||||||
Depreciation, depletion, and amortization | 35,649 | 3,307 | 799 | 39,755 | ||||||||||||
Gains on derivatives | (6,847 | ) | — | — | (6,847 | ) | ||||||||||
Net cash paid for scheduled derivative settlements | (12,524 | ) | — | — | (12,524 | ) | ||||||||||
Other operating (income) expenses | (1,093 | ) | (610 | ) | 670 | (1,033 | ) | |||||||||
Stock compensation expense | 105 | 184 | 3,263 | 3,552 | ||||||||||||
Acquisition costs(1) | 972 | — | — | 972 | ||||||||||||
Adjusted EBITDA | $ | 78,274 | $ | 7,689 | $ | (16,908 | ) | $ | 69,055 |
__________
(1) Includes costs related to the acquisition of
Three Months Ended | ||||||||||||||||
E&P | Well Servicing and Abandonment | Corporate/ Eliminations | ||||||||||||||
(unaudited) (in thousands) | ||||||||||||||||
Adjusted EBITDA reconciliation to net income (loss): | ||||||||||||||||
Net income (loss) | $ | 24,170 | $ | 2,114 | $ | (32,143 | ) | $ | (5,859 | ) | ||||||
Add (Subtract): | ||||||||||||||||
Interest expense | — | 5 | 7,832 | 7,837 | ||||||||||||
Income tax benefit | — | — | (2,913 | ) | (2,913 | ) | ||||||||||
Depreciation, depletion, and amortization | 33,835 | 3,256 | 3,030 | 40,121 | ||||||||||||
Gains on derivatives | (39,109 | ) | — | — | (39,109 | ) | ||||||||||
Net cash received for scheduled derivative settlements | 47,467 | — | — | 47,467 | ||||||||||||
Other operating expenses (income) | 1,809 | (82 | ) | (2,013 | ) | (286 | ) | |||||||||
Stock compensation expense | 312 | 145 | 4,309 | 4,766 | ||||||||||||
Non-recurring costs(1) | 7,313 | — | — | 7,313 | ||||||||||||
Adjusted EBITDA | $ | 75,797 | $ | 5,438 | $ | (21,898 | ) | $ | 59,337 |
__________
(1) Non-recurring costs included executive transition and workforce reduction costs in the first quarter of 2023.
Three Months Ended | ||||||||||||||||
E&P | Well Servicing and Abandonment | Corporate/ Eliminations | ||||||||||||||
(unaudited) (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 expense | — | — | 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 (income) | 30 | (210 | ) | 533 | 353 | |||||||||||
Stock compensation expense | 380 | 86 | 3,954 | 4,420 | ||||||||||||
Adjusted EBITDA | $ | 116,942 | $ | 6,200 | $ | (13,395 | ) | $ | 109,747 | |||||||
ADJUSTED FREE CASH FLOW
The following table presents a reconciliation of the non-GAAP financial measure Adjusted Free Cash Flow to the GAAP financial measure of operating cash flow for each of the periods indicated. The Company uses Adjusted Free Cash Flow for its shareholder return model, which began in 2022.
Three Months Ended | ||||||||||||
(unaudited) (in thousands) | ||||||||||||
Adjusted Free Cash Flow: | ||||||||||||
Net cash provided by operating activities(1) | $ | 62,538 | $ | 1,781 | $ | 111,242 | ||||||
Subtract: | ||||||||||||
Maintenance capital(2) | (19,625 | ) | (19,272 | ) | (32,134 | ) | ||||||
Fixed dividends(3) | (9,139 | ) | (9,190 | ) | (4,726 | ) | ||||||
Adjusted Free Cash Flow | $ | 33,774 | $ | (26,681 | ) | $ | 74,382 |
__________
(1) On a consolidated basis.
(2) Maintenance capital is the capital required to keep annual production substantially flat, and is calculated as follows:
Three Months Ended | ||||||||||||
(unaudited) (in thousands) | ||||||||||||
Consolidated capital expenditures(a) | $ | (21,895 | ) | $ | (20,633 | ) | $ | (34,086 | ) | |||
Excluded items(b) | 2,270 | 1,361 | 1,952 | |||||||||
Maintenance capital | $ | (19,625 | ) | $ | (19,272 | ) | $ | (32,134 | ) |
__________
(a) Capital expenditures include capitalized overhead and interest and excludes acquisitions and asset retirement spending.
(b) Comprised of the capital expenditures in the Company's E&P segment that are related to strategic business expansion, such as acquisitions of oil and gas properties and any exploration and development activities to increase production beyond the prior year’s annual production volumes and capital expenditures in the Company's well servicing and abandonment segment and corporate expenditures that are related to ancillary sustainability initiatives or other expenditures that are discretionary and unrelated to maintenance of the Company's core business. For the three months ended
(3) Represents fixed dividends declared for the periods presented.
ADJUSTED NET INCOME (LOSS)
The following table presents a reconciliation of the non-GAAP financial measure Adjusted Net Income (Loss) to the GAAP financial measure of net income (loss) and Adjusted Net Income (Loss) per share — diluted to net income per share — diluted.
Three Months Ended | ||||||||||||||||||||||||
(in thousands) | per share – diluted | (in thousands) | per share – diluted | (in thousands) | per share – diluted | |||||||||||||||||||
(unaudited) | ||||||||||||||||||||||||
Adjusted Net Income (Loss) reconciliation to net income (loss): | ||||||||||||||||||||||||
Net income (loss) | $ | 25,770 | $ | 0.33 | $ | (5,859 | ) | $ | (0.07 | ) | $ | 43,354 | $ | 0.52 | ||||||||||
Add (Subtract): | ||||||||||||||||||||||||
(Gains) losses on derivatives | (6,847 | ) | (0.09 | ) | (39,109 | ) | (0.49 | ) | 51,319 | 0.62 | ||||||||||||||
Net cash (paid) received for scheduled derivative settlements | (12,524 | ) | (0.16 | ) | 47,467 | 0.60 | (37,628 | ) | (0.45 | ) | ||||||||||||||
Other operating (income) expenses | (1,033 | ) | (0.01 | ) | (286 | ) | (0.01 | ) | 353 | 0.01 | ||||||||||||||
Acquisition costs(1) | 972 | 0.01 | — | — | — | — | ||||||||||||||||||
Non-recurring costs(2) | — | — | 7,313 | 0.09 | — | — | ||||||||||||||||||
Total additions (subtractions), net | (19,432 | ) | (0.25 | ) | 15,385 | 0.19 | 14,044 | 0.18 | ||||||||||||||||
Income tax expense (benefit) of adjustments(3) | 5,328 | 0.07 | (4,219 | ) | (0.05 | ) | (3,807 | ) | (0.05 | ) | ||||||||||||||
Adjusted Net Income | $ | 11,666 | $ | 0.15 | $ | 5,307 | $ | 0.07 | $ | 53,591 | $ | 0.65 | ||||||||||||
Basic EPS on Adjusted Net Income | $ | 0.15 | $ | 0.07 | $ | 0.67 | ||||||||||||||||||
Diluted EPS on Adjusted Net Income | $ | 0.15 | $ | 0.07 | $ | 0.65 | ||||||||||||||||||
Weighted average shares of common stock outstanding – basic | 76,721 | 76,112 | 79,596 | |||||||||||||||||||||
Weighted average shares of common stock outstanding – diluted | 79,285 | 79,210 | 83,015 |
__________
(1) Includes costs related to the acquisition of
(2) Non-recurring costs included executive transition costs and workforce reduction costs in the first quarter of 2023.
(3) The federal and state statutory rates were utilized in both 2023 and 2022. We updated the disclosure in 2022 to reflect the 2022 statutory rate, instead of the effective tax rate previously utilized.
ADJUSTED GENERAL AND ADMINISTRATIVE EXPENSES
The following table presents a reconciliation of the non-GAAP financial measure Adjusted General and Administrative Expenses to the GAAP financial measure of general and administrative expenses for each of the periods indicated.
Three Months Ended | ||||||||||||
(unaudited) ($ in thousands) | ||||||||||||
Adjusted General and Administrative Expense reconciliation to general and administrative expenses: | ||||||||||||
General and administrative expenses | $ | 22,488 | $ | 31,669 | $ | 23,183 | ||||||
Subtract: | ||||||||||||
Non-cash stock compensation expense (G&A portion) | (3,379 | ) | (4,619 | ) | (4,263 | ) | ||||||
Non-recurring costs(1) | — | (7,313 | ) | — | ||||||||
Adjusted General and Administrative Expenses | $ | 19,109 | $ | 19,737 | $ | 18,920 | ||||||
Well servicing and abandonment segment | $ | 2,958 | $ | 3,126 | $ | 3,285 | ||||||
E&P segment, and corporate | $ | 16,151 | $ | 16,611 | $ | 15,635 | ||||||
E&P segment, and corporate ($/boe) | $ | 6.84 | $ | 7.60 | $ | 6.55 | ||||||
Total mboe | 2,361 | 2,187 | 2,386 |
__________
(1) Non-recurring costs included executive transition costs and workforce reduction costs in the first quarter of 2023.
Contact Contact:Berry Corporation (bry) Todd Crabtree – Director, Investor Relations (661) 616-3811 ir@bry.com
Source:
2023 GlobeNewswire, Inc., source