Berry Corporation (bry) Reports Fourth Quarter and Full-Year 2020 Results; Reinstates a Quarterly Dividend

By Benzinga13 days ago


DALLAS, Feb. 23, 2021 (GLOBE NEWSWIRE) -- Berry Corporation (bry) (NASDAQ:BRY) (“Berry“ or the “Company“) today reported fourth quarter and full-year 2020 results. For the full year Berry's net loss was $263 million, or $3.29 per diluted share, and Adjusted Net Income(1) was $45 million, or $0.56 per diluted share. For the fourth quarter the net loss was $64 million, or $0.80 per diluted share, and Adjusted Net Income(1) was $9 million, or $0.11 per diluted share. In addition, the Company's Board of Directors approved a first quarter dividend of $0.04 per share.

Highlights for the Quarter

  • Generated $33 million in Levered Free Cash Flow(1)
  • Restarted development program with two rigs part time, drilling 22 wells, all California oil
  • Adjusted EBITDA(1) of $54 million
  • 88% oil production mix
  • Capital expenditures of $12 million with approximately 96% directed to California development

Highlights for the Full Year

  • Generated $131 million in Levered Free Cash Flow(1)
  • Ended year with cash balance of $80 million
  • Adjusted EBITDA(1) of $244 million
  • Reduced 2020 OpEx by $1.81/Boe
  • Increased California oil production more than 1% from 2019 volumes
  • Oil production of 25,000 Boe/d comprising 88% of total production
  • Capital expenditures of $69 million, approximately 96% directed to California assets

(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.

“One of Berry's core financial tenets has always been to live out of Levered Free Cash Flow while protecting our base production. Even in the midst of an unprecedented year, we successfully delivered our plan. We adeptly improved our hedge position before prices plummeted, lowered our costs, and maximized our cash position to weather the volatile environment that was 2020. We committed to all stakeholders that we would enter 2021 in a strong position poised for growth and we are,“ said Trem Smith, Berry board chair and chief executive officer. “We started 2021 in a strong liquidity position by continuing our cash build and currently have more than $100 million. For 2021, we will utilize our proven financial formula of operating within our Levered Free Cash Flow and returning capital to our shareholders. We are pleased to announce the return of a quarterly dividend justified by the improving price environment, our growing confidence in the business fundamentals for oil and our strong liquidity position. Our cash position and improving oil prices, allow us to put capital to work protecting and growing our California production. We plan to hold year-over-year company-wide production flat in 2021 and anticipate a strong fourth quarter exit rate. In addition, we are laser focused on increasing our scale. Our growth strategy continues to be directed toward conventional, low corporate decline assets with strong visibility to cash flow.“

Fourth Quarter 2020 Results

Adjusted EBITDA(1) on a hedged basis, was $54 million in the fourth quarter 2020, compared to $62 million in the third quarter 2020, reflecting lower volumes, as well as lower electricity sales due to seasonal effects and higher workover activity driving higher Operating Expenses (OpEx).

Average daily production in the fourth quarter 2020 of 26,600 Boe/d was 4% lower than the third quarter volumes of 27,600 Boe/d due mainly to natural decline resulting from pausing drilling activity for the majority of the year, with drilling restarting during the fourth quarter. Company-wide oil production declined 3% sequentially and California oil production, which is 80% of total production, was 21,200 MBoe/d for the fourth quarter.

The Company-wide hedged realized oil price for the fourth quarter 2020 was $56.41/Bbl, essentially flat from the third quarter. The financial hedges for oil sales for the fourth quarter 2020 added $15.03/Bbl to the realized price, highlighting the effectiveness of the Company's oil hedge positions in 2020. Company-wide realized oil prices before hedges of $41.38/Bbl was 4% higher in the fourth quarter 2020 compared to the third quarter.

California's unhedged realized oil price in the fourth quarter increased 4% or $1.72 per Bbl to $41.74, which was 92% of Brent and unchanged from the previous quarter. Rockies' unhedged realized oil price declined 2% to $37.56 per Bbl but the Company-wide average price increased 15% as the natural gas price increased 43% to $2.78 per Mcf. The total Company average oil and gas price increased 5% to $38.28 per Boe in the fourth quarter 2020 from $36.35 in the third quarter.

Levered Free Cash Flow(1) for the fourth quarter 2020 was $33 million, after $12 million of capital expenditures and $8 million of interest.

OpEx increased to $19.06/Boe for the fourth quarter 2020, compared to $16.97/Boe in the third quarter. This $4 million increase in OpEx was primarily due to the seasonal effect of lower electricity capacity revenues, as well as the workover and recompletion campaign which began during the fourth quarter, higher natural gas fuel prices, as well as general facility and well maintenance.

General and administrative expenses increased by $1 million, or 6%, to approximately $20 million for the fourth quarter 2020, compared to the third quarter of 2020. Adjusted General and Administrative Expenses(1), which excludes non-cash stock compensation costs and nonrecurring costs, were $15 million and $14 million for the fourth and third quarter of 2020, respectively. The higher fourth quarter 2020 expenses reflect increased employee compensation accruals.

Taxes, other than income taxes were $4.43 per Boe in the fourth quarter compared to $3.91 in the third quarter. The increase was largely due to annual property tax assessments in the quarter.

Capital expenditures, which were focused on development activities in California, increased to $12 million for the fourth quarter compared to $4 million for the third quarter. This was due to resuming California drilling activity after more than six months of not drilling because of low prices and an oversupply in the market. These amounts exclude capitalized overhead and interest costs of $2 million for the fourth quarter and expenditures for asset retirement obligation of $4 million.

Full-Year 2020 Results

Adjusted EBITDA(1) (hedged) was $244 million for 2020, a decrease of $58 million compared to 2019 primarily due to lower commodity prices and, to a much lesser degree, lower volumes due to the pause of drilling from April to October related to pricing. Offsetting a portion of the price impact was a $22 million reduction in OpEx.

Year-over-year California production increased over 1% to 22,900 Bbl/d, while overall Company production decreased 2% to 28,500 Boe/d in 2020 due to the natural decline of our Rockies properties in the absence of development activity.

California's unhedged realized oil price was $40.01 per Bbl in 2020 and $60.51 in 2019. Rockies' unhedged realized oil price declined to $34.69 per Bbl from $45.78 in 2019. Total Company average oil and gas price decreased $17.10 per Boe from 2019 to $36.29 in 2020. Oil hedge settlements increased to $16.51 per Bbl ($152 million) in 2020 from $4.68 per Bbl in the previous year.

OpEx on a hedged basis decreased $1.81 per Boe, or $22 million from 2019 to $18.51 in 2020. As a result of cost saving and efficiency measures implemented in 2020, Non-Energy OpEx decreased $15 million, or $1.17 per Boe, when compared to the prior year. Energy OpEx decreased $7 million or $0.63 per Boe.

General and administrative expenses increased by $15 million, or 24%, to approximately $78 million for the year ended December 31, 2020, compared to the prior year. Adjusted General and Administrative Expenses(1), which excludes non-cash stock compensation costs and nonrecurring costs, were $57 million and $51 million in 2020 and 2019, respectively. The year-over-year increase is due to higher employee compensation and increased activities necessary for our participation in the regulatory and legislative process primarily in California.

Taxes, other than income taxes, decreased to $3.41/Boe in 2020 from $3.84/Boe in 2019. The decrease was largely due to lower greenhouse gas prices during 2020 including some allowance purchases made at low prices due to a temporary market dislocation in the first quarter of 2020, as well as lower CO2 emissions. Partially offsetting the greenhouse gas prices were higher property tax rates, as well as higher severance tax rates due to the expiration of certain deductions.

Capital expenditures totaled $69 million for 2020 compared to $209 million for 2019. The decrease was due primarily to the reduction in drilling with 45 wells in 2020 compared to 338 in 2019. These amounts exclude capitalized overhead and interest costs. Additionally, we spent $18 million in 2020 on plugging and abandonment activities. Capital was largely focused on development drilling in California, which accounted for 96% of 2020 development capital.

Proved reserves were 95 MMBoe at December 31, 2020, of which 91% are located in California and where 97% of the PV-10(1) value is located. The formulaic SEC oil price used to calculate proved reserves decreased 34% year-over-year, which drove a 26% reduction in our proved reserves, before the effect of current year production. Additionally, the significant drop in commodity prices during the year resulted in a significant decline in the Company's capital program, limiting opportunities to prove-up additional reserves. The Company drilled 87% fewer wells in 2020 than in the prior year. Based on current Brent strip pricing the Company anticipates a material improvement in 2021 proved reserves, should prices remain at those levels.

As of December 31, 2020, the elected commitment under Berry's reserves-based lending credit facility (“RBL Facility“) was $200 million with no outstanding borrowings. The Company had $193 million available for borrowing under the RBL Facility which included $7 million of outstanding letters of credit.

“We delivered on the promises we made last spring to bridge to the end of 2021 as the pandemic took its hold on the global economy. At the time, we planned for a two-year down-cycle in our industry. We immediately began to cut costs and leverage our strong hedge position in an effort to preserve cash for 2021. At year-end, we had more than $80 million of cash in the bank and currently we have more than $100 million. For 2021, we plan to deploy $120 to $130 million of capital, which should keep our production relatively flat on an annual basis, with an accelerated rate exiting 2021. Like 2020, we plan to see oil growth in our attractive California basin,“ stated Cary Baetz, executive vice president and chief financial officer. “Notably, our reserve calculations were negatively impacted by the severe price correction caused by the Saudi/Russia market dispute earlier in the year and demand erosion due to Covid-19. However, for 2021, we expect a substantial improvement in our calculated reserves as the current strip prices are more than 40% higher than the SEC prices used for the 2020 reserve calculation.“

(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.

Quarterly Dividend

The Company's Board of Directors declared a regular dividend for the first quarter of 2021 at a rate of $0.04 per share on the Company's outstanding common stock, payable on April 15, 2021 to shareholders of record at the close of business on March 15, 2021. This is the Company's first regular quarterly dividend since its suspension during the price decline in early 2020 related to the pandemic and commodities markets.

Subject to approval by the Board and depending on a variety of factors, including the Company's financial condition and results of operations, the Company intends to pay a similar dividend in future quarters.

Full-Year 2021 Guidance

The Company expects to employ up to three drilling rigs in California during 2021. Additionally, the Company anticipates drilling approximately 170 to 200 gross development wells during 2021, almost all of which will be in California for oil production.

Full-Year 2021 Guidance LowHigh
Average Daily Production (MBoe/d)27.029.0
Oil as % of Production~89%
Operating Expenses ($/Boe)$17.25$18.55
Taxes, Other than Income Taxes ($/Boe)$3.75$4.25
Adjusted General & Administrative (G&A) expenses ($/Boe)$5.50$6.25
Capital Expenditures ($ millions)$120$130
New Drill Wells170200

Earnings Conference Call

Berry will host a conference call February 24, 2021 to discuss these results:

Live Call Date:Wednesday, February 24, 2021
Live Call Time:9:00 a.m. Eastern Time (6 a.m. Pacific Time)
Live Call Dial-in:877-491-5169 from the U.S.
720-405-2254 from international locations
Live Call Passcode:1256432

A live audio webcast will be available on the “Events“ section of Berry's website at

An audio replay will be available shortly after the broadcast:

Replay Dates:Through Wednesday, March 10, 2021
Replay Dial-in:855-859-2056 from the U.S.
404-537-3406 from international locations
Replay Passcode:1256432

A replay of the audio webcast will also be archived on the “Reports & Resources“ section of Berry's website at

About Berry Corporation (bry)

Berry is a publicly traded (NASDAQ:BRY) western United States independent upstream energy company with a focus on the conventional, long-lived oil reserves in the San Joaquin basin of California. More information can be found at the Company's website at

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 financial position; liquidity; cash flows; anticipated financial and operating, results; capital program and development and production plans; operations and business strategy; potential acquisition opportunities; reserves; hedging activities; capital expenditures, return of capital; payment, improvement of future dividends; future repurchases of stock or debt; capital investments, 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 regulatory approval and permitting requirements; the impact and duration of the ongoing COVID-19 pandemic on demand and pricing levels; 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 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 risks; effects of hedging arrangements; potential shut-ins of production due to lack of downstream demand or storage capacity; 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, 2020.

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


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.


Quarter EndedDecember 31,
Quarter EndedSeptember 30,
Quarter EndedDecember 31,
Year EndedDecember 31,
Year EndedDecember 31,
($ and shares in thousands, except per share amounts)
Consolidated Statement of Operations Data:
Revenues and other:
Oil, natural gas and natural gas liquids sales$93,811$92,239$156,336$378,663$565,596
Electricity sales6,7248,7446,84425,81329,397
(Losses) gains on oil and gas sales derivatives(39,617)(11,564)(45,544)117,781(37,998)
Marketing revenues3513304371,4262,094
Other revenues9755150316
Total revenues and other61,36689,749118,128523,833559,405
Expenses and other:
Lease operating expenses49,62145,24359,529186,348216,294
Electricity generation expenses5,4224,2174,78516,60819,490
Transportation expenses1,5591,7682,1246,9388,059
Marketing expenses3443264031,3802,073
General and administrative expenses20,40919,17315,71077,69662,643
Depreciation, depletion and amortization30,43435,90530,102139,180106,006
Impairment of oil and gas properties51,081289,08551,081
Taxes, other than income taxes10,8589,91311,96235,57240,645
Losses (gains) on natural gas purchase derivatives3,859(15,784)(3,385)1,0356,957
Other operating expenses (income)3,1231,6487745,7814,588
Total expenses and other125,629102,409173,085759,623517,836
Other (expenses) income:
Interest expense(8,308)(8,391)(7,871)(34,295)(34,234)
Other, net(13)(3)(28)80
Total other (expenses) income(8,321)(8,394)(7,871)(34,323)(34,154)
Reorganization items, net(426)
(Loss) income before income taxes(72,584)(21,054)(62,828)(270,113)6,989
Income tax (benefit) expense(8,754)(2,190)(55,844)(7,218)(36,550)
Net (loss) income$(63,830)$(18,864)$(6,984)$(262,895)$43,539
Net (loss) earnings per share:
Weighted-average common shares outstanding - basic79,92279,87980,43579,80281,379
Weighted-average common shares outstanding - diluted79,92279,87980,43579,80281,951
Adjusted Net Income(1)$8,580$13,452$33,189$44,816$110,228
Weighted-average common shares outstanding - diluted80,03380,06280,78879,90281,951
Diluted earnings per share on Adjusted Net Income$0.11$0.17$0.41$0.56$1.35
Adjusted EBITDA(1)$53,682$61,515$86,995$244,430$302,184
Adjusted EBITDA unhedged(1)$18,365$26,039$71,529$102,138$259,987
Levered Free Cash Flow(1)$33,011$49,129$28,298$131,451$20,127
Levered Free Cash Flow Unhedged(1)$(2,306)$13,653$12,832$(10,841)$(22,070)
Adjusted General and Administrative Expenses(1)$14,881$13,888$13,421$57,406$51,226
Effective Tax Rate, including discrete items12%10%89%3%(523)%
Cash Flow Data:
Net cash provided by operating activities$52,110$57,997$77,562$196,529$241,829
Net cash used in investing activities$(19,098)$(9,004)$(63,739)$(93,620)$(225,025)
Net cash used in financing activities$(75)$(1,373)$(28,675)$(22,352)$(85,484)

(1) See further discussion and reconciliation in “Non-GAAP Financial Measures and Reconciliations“.

December 31, 2020December 31, 2019
($ and shares in thousands)
Balance Sheet Data:
Total current assets$154,491$100,432
Total property, plant and equipment, net$1,258,084$1,576,267
Total current liabilities$175,306$156,628
Long-term debt$393,480$394,319
Total stockholders' equity$714,036$972,448
Outstanding common stock shares as of79,92979,543


The following table shows a summary by area of our selected historical financial information and operating data for the periods indicated.

California(San Joaquin and Ventura
Utah(Uinta basin)Colorado(Piceance basin)
Year EndedDecember 31,
Year EndedDecember 31,
Year EndedDecember 31,
Year EndedDecember 31,
Year EndedDecember 31,
Year EndedDecember 31,
($ in thousands, unless noted otherwise)
Oil, natural gas and natural gas liquids sales$335,642$498,325$37,481$59,383$

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