UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
FORM 8-K
CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
Date of Report (Date of earliest event reported): May 3, 2005 (May 3, 2005)
BERRY PETROLEUM COMPANY
DELAWARE (State or Other Jurisdiction of Incorporation or Organization) |
1-9735 (Commission File Number) |
77-0079387 (IRS Employer Identification Number) |
5201 TRUXTUN AVE., STE. 300, BAKERSFIELD,
CA (Address of Principal Executive Offices) |
93309 (Zip Code) |
Registrants telephone number, including area code: (661) 616-3900
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
o Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
o Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
o Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
o Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))
Item 2.02 | Results of Operations and Financial Condition |
On May 3, 2005,
Berry Petroleum Company issued a news release announcing its financial results
for its first fiscal quarter ended March 31, 2005. The information contained in
the press release is incorporated herein by reference and furnished as Exhibit
99.1.
The information in this Current Report on Form 8-K and
Exhibit 99.1 is being furnished and shall not be deemed "filed" for the purposes
of Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise
subject to the liabilities of that Section.
Item 9.01 | Financial Statements and Exhibits |
(c) Exhibits
99.1 Press release dated May 3, 2005 announcing the Registrant's financial
results for the quarter ended March 31, 2005.
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereto duly authorized.
BERRY PETROLEUM COMPANY |
||||
By: |
/s/ Kenneth A. Olson |
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Kenneth A. Olson | ||||
Corporate Secretary | ||||
Date: May 3, 2005
Page 2 of 2
News Release - May 3, 2005
Berry Petroleum Company Phone (661) 616-3900
5201 Truxtun Avenue, Suite
300 E-mail:
ir@bry.com
Bakersfield, California
93309-0640 Internet:
www.bry.com
Contacts: Robert F. Heinemann, President and CEO - - Ralph J. Goehring,
Executive Vice President and CFO
BERRY PETROLEUM REPORTS FIRST QUARTER 2005 RESULTS
Bakersfield, CA - May 3, 2005 - Berry Petroleum Company (NYSE:BRY) announced net
income of $22.5 million, or $1.00 per diluted share for the first quarter of
2005, up 116% from net income of $10.4 million, or $.47 per diluted share in the
first quarter of 2004. Revenues rose to a record $88 million in the quarter, up
54% from $57.3 million in the first quarter of 2004. The Company's average daily
production of 22,047 barrels of oil equivalent (BOE) increased by 14% over a
year ago and the average realized sales price of $37.81 per BOE was up 48% from
the $25.58 per BOE achieved in the first quarter of 2004, according to Robert F.
Heinemann, president and chief executive officer.
Mr. Heinemann continued, "Berry reported another excellent quarter of earnings.
We continue our strategy of growing production and reserves from existing assets
through development, while seeking acquisitions with significant upside
potential. In the first quarter, we drilled 35 development wells, performed 19
workovers, and completed the purchase of our first Mid-Continent asset in Yuma
County, Colorado in late January. With this acquisition, Berry achieved a record
22,047 BOE per day production, up 3% from our 2004 fourth quarter production of
21,410 BOE per day. Reported production was negatively impacted by approximately
450 BOE per day due to the conversion of a royalty interest into a working
interest on one of our California properties in December 2004. Natural gas
production averaged 17 million cubic feet (MMcf) per day in the first quarter of
2005, mostly due to our Yuma County Niobrara gas production, which brings our
production mix to 87% oil and 13% gas. This asset is a great fit for Berry as it
offers long-lived, proved reserves, enhances our development drilling inventory
with low geologic risk, and provides opportunities to increase our asset
position in the region. We have drilled five new gas wells to-date in Yuma
County, have 80 wells permitted and plan to drill at least 60 wells in 2005.
"Our assets in California, the Rockies and Mid-Continent are all performing well
and we are excited about our appraisal drilling planned for the summer of 2005.
This program includes drilling our Green River oil prospects at Lake Canyon,
drilling our Ferron gas wells at Coyote Flats and expanding our diatomite pilot
at North Midway Sunset. We have started the appraisal drilling of our Tri-State
acreage, located adjacent to the Yuma County Niobrara asset. The first well in
Sherman County, Kansas was drilled and is being tested and evaluated. Our
partner will drill the first horizontal well on the Tri-State acreage in May.
While Berry is not immune to the well permitting and rig availability challenges
experienced by several producers in the Rockies, we look forward to facing the
challenges of our production goals for this year", Heinemann said.
The Company's operating costs in the first quarter of 2005 were up 6% on a per
BOE basis to $11.80 from $11.09 in the fourth quarter of 2004, due to higher
severance taxes and higher well servicing costs. The Company anticipates
operating costs to average between $11.75 and $12.75 per BOE for all of 2005. In
the first quarter, the Company had a $2 million charge from two dry holes, one
at the Midway-Sunset field in California and one at the Coyote Flats prospect in
Utah.
Ralph J. Goehring, executive vice president and chief financial officer said,
"Berry's performance in the first quarter was excellent and reflects a continued
improvement in the price of crude oil. We believe our cash from operations for
2005 will well exceed our projected capital expenditures of $107 million. Our
long-term debt increased in the first quarter to $138 million as we closed on
the Niobrara gas assets ($105 million purchase price) and the Tri-State acreage
($5 million purchase price). Our financial position remains very strong and we
expect to put our cash to work where we can generate excellent returns to our
shareholders. In 2004 we achieved an excellent 26% return on capital employed
and will attempt to surpass that in 2005. Our excess cash is first earmarked for
acquisition opportunities and second for debt reduction. We have in place for
2005 an attractive sales agreement for our California heavy crude. The Company
has approximately 7,750 barrels per day hedged for calendar 2005 at
approximately WTI NYMEX $40.75 per barrel. In the first quarter we added hedges
on 2,000 barrels per day for the first nine months of 2006 at an average WTI
price of $47.00. The Company's hedge position can be viewed at:
www.bry.com/index.php?page=hedging."
Regional Activity Update
Excluding future acquisitions, the Company plans to spend approximately $107
million in 2005 on drilling 177 net wells and performing 92 workovers. In the
first quarter of 2005, the Company spent $15.7 million on capital expenditures
and intends to fund 100% of its capital program out of internally generated cash
flow. Continuing areas of focus in 2005 will be:
*California production - The Company drilled 17 wells in California in the
first quarter of 2005, and has completed all of the eight planned infill
horizontal wells at Midway-Sunset. Other California drilling will include
expanding the thermal development of the Poso Creek field, where production has
reached over 500 BOE per day, and at the Company's diatomite exploitation at
North Midway-Sunset where production has ramped up to 100 BOE per day.
*Rockies & Mid-Continent production - In 2005 the Company will continue to
develop the Brundage Canyon asset on 80-acre spacing, test the potential of
40-acre infill drilling and appraise the northern and southern limits of the
field. On the recently acquired Yuma County Niobrara gas assets, the Company has
drilled five wells and plans to drill approximately 60 wells as part of its
ongoing development program and to begin the 40-acre infill program on the
existing 80-acre development.
*Rockies & Mid-Continent prospects - The Company has two Green River oil wells
permitted for May 2005 drilling at its Lake Canyon acreage. These initial drill
sites will be approximately three miles west of the Company's Brundage Canyon
field. Berry will participate in the acquisition of 50 square miles of 3D
seismic at Lake Canyon this summer. This seismic will aid in determining the
location for the drilling of the first deep Mesaverde natural gas test well in
Lake Canyon scheduled for late 2005.
In summer 2005 the Company intends
to drill an offset well at Coyote Flats (45 miles southwest of Brundage Canyon)
about one mile from the Scofield-Thorpe gas discovery well drilled in 2002 to a
depth of 6,800 feet in the Ferron sands. The discovery well tested for 30 days
with a peak rate of 1.1 MMcf per day. Successful completion of this offset well
will allow the Company
to begin designing
new infrastructure in the area.The Company will participate in
the drilling of the first horizontal well in the Niobrara gas formation later
this month at the recently acquired Tri-State acreage in Colorado, Nebraska and
Kansas. Berry also plans to participate in the acquisition of approximately 530
miles of 2D seismic
in this region
beginning in the second quarter of 2005.
Teleconference Call
A conference call will be held Tuesday, May 3, 2005 at 11:00 a.m. Eastern Time
(8:00 a.m. Pacific Time). Dial 1-866-800-8651 to participate, using passcode
75154868. International callers may dial 617-614-2704. For a digital replay
available until May 17, 2005, dial 1-888-286-8010 (passcode 82298538). Listen
live or via replay on the Web at www.bry.com.
Transcripts of this and previous calls may be viewed at www.bry.com/tele.htm.
Berry Petroleum Company is a publicly traded independent oil and gas production
and exploitation company with its headquarters in Bakersfield, California.
Safe Harbor
"Safe harbor under the Private Securities Litigation Reform Act of 1995:" With
the exception of historical information, the matters discussed in this news
release are forward-looking statements that involve risks and uncertainties.
Although the Company believes that its expectations are based on reasonable
assumptions, it can give no assurance that its goals will be achieved. Important
factors that could cause actual results to differ materially from those in the
forward-looking statements herein include, but are not limited to: the timing
and extent of changes in commodity prices for oil, gas and electricity;
exploration, drilling, development and operating risks; a limited marketplace
for electricity sales within California, counterparty risk; acquisition risks;
competition, environmental risks, litigation uncertainties; the availability of
drilling rigs and other support services, pipeline capacity restraints, legislative and/or judicial decisions
and other government or Tribal regulations.
CONDENSED INCOME STATEMENTS | |||
(In thousands, except per share data) | |||
(unaudited) | |||
Three Months Ended | |||
3/31/2005 | 3/31/2004 | ||
Revenues | |||
Sales of oil and gas | $75,391 | $45,205 | |
Sales of electricity | 12,456 | 11,934 | |
Interest and other income, net | 148 | 203 | |
Total | 87,995 | 57,342 | |
Expenses | |||
Operating costs - oil gas production | 23,407 | 16,782 | |
Operating costs - electricity generation | 13,358 | 12,403 | |
Exploration costs | 561 | - | |
Depreciation, depletion & amortization - oil & gas | 8,527 | 6,354 | |
Depreciation, depletion & amortization - electricity | 772 | 855 | |
General and administrative | 4,820 | 7,344 | |
Dry hole, abandonment & impairment | 2,021 | - | |
Interest | 1,162 | 531 | |
Total | 54,628 | 44,269 | |
Income before income taxes | 33,367 | 13,073 | |
Provision for income taxes | 10,862 | 2,709 | |
Net income | $22,505 | $10,364 | |
Basic net income per share | $1.02 | $ .48 | |
Diluted net income per share | $1.00 | $ .47 | |
Cash dividends per share | $.12 | $ .11 | |
Weighted average capital stock outstanding: | |||
Basic | 21,981 | 21,817 | |
Diluted | 22,470 | 22,083 | |
CONDENSED BALANCE SHEETS | |||
(In thousands) | |||
(unaudited) | |||
3/31/2005 | 12/31/2004 | ||
Assets | |||
Current assets | $ 84,481 | $ 61,001 | |
Properties, buildings & equipment, net | 462,407 | 338,706 | |
Other assets & deposits | 5,909 | 12,397 | |
$552,797 | $412,104 | ||
Liabilities & Shareholders' Equity | |||
Current liabilities | $ 85,628 | $ 64,841 | |
Deferred income taxes | 51,783 | 47,963 | |
Long-term debt | 138,000 | 28,000 | |
Other long-term liabilities | 12,139 | 8,214 | |
Shareholders' equity | 265,247 | 263,086 | |
$552,797 | $412,104 | ||
CONDENSED STATEMENTS OF CASH FLOWS | |||
(In thousands) | |||
(unaudited) | |||
Three Months Ended | |||
3/31/2005 | 3/31/2004 | ||
Cash flows from operating activities: | |||
Net income | $22,505 | $10,364 | |
Depreciation, depletion & amortization (DD&A) | 9,299 | 7,209 | |
Abandonment costs | (213) | (105) | |
Deferred income taxes | 5,042 | 2,270 | |
Deferred stock-based compensation expense | 376 | 3,240 | |
Other, net | 89 | 147 | |
Net changes in operating assets and liabilities | (17,846) | (3,559) | |
Net cash provided by operating activities | 19,252 | 19,566 | |
Net cash used in investing activities | (125,150) | (18,440) | |
Net cash provided by (used in) financing activities | 107,358 | (2,401) | |
Net (decrease) increase in cash and cash equivalents | 1,460 | (1,275) | |
Cash and cash equivalents at beginning of year | 16,690 | 10,658 | |
Cash and cash equivalents at end of period | $18,150 | $9,383 | |
COMPARATIVE OPERATING STATISTICS | |||
in thousands (except Per BOE data) | |||
(unaudited) | |||
Three Months Ended | |||
3/31/2005 | 3/31/2004 | Change | |
Oil and gas: | |||
Net production-BOE per day | 22,047 | 19,395 | +14% |
Per BOE: | |||
Average sales price before hedging | $40.89 | $28.26 | +45% |
Average sales price after hedging | 37.81 | 25.58 | +48% |
Operating costs | 11.80 | 9.51 | +24% |
DD & A | 4.30 | 3.60 | +19% |
General & administrative expenses | 2.43 | 4.16 | -42% |
Interest expense | $ .59 | $ .30 | +97% |
Electricity: | |||
Electric power produced - Megawatt hours/day | 2,117 | 2,167 | -2% |
Electric power sold - Megawatt hours/day | 1,918 | 1,956 | -2% |
Average sales price - $/MWh | $68.87 | $67.05 | +3% |
Fuel gas cost - $/MMBtu | $ 5.74 | $ 5.09 | +13% |
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