Clayton Williams Energy, Inc. (the “Company”) (NASDAQ: CWEI)
today reported its financial results for the third quarter of
2010.
Financial Results
Net income attributable to Company stockholders for the third
quarter of 2010 was $11.6 million, or $.96 per share, as compared
to a net loss of $13.6 million, or $1.12 per share, for the third
quarter of 2009. Cash flow from operations for the third quarter of
2010 was $57.5 million as compared to $28.3 million during the same
period in 2009.
For the nine months ended September 30, 2010, net income
attributable to Company stockholders was $42.3 million, or $3.48
per share, as compared to a net loss of $74.5 million, or $6.14 per
share, for the same period in 2009. Cash flow from operations for
the nine-month period in 2010 was $154.2 million as compared to
$68.2 million during the same period in 2009.
The key factors affecting the comparability of financial results
for the third quarter of 2010 (“3Q10”) versus the third quarter of
2009 (“3Q09”) were:
- Oil and gas sales increased $22.5
million in 3Q10 versus 3Q09. Production variances accounted for
$12.3 million of this increase, and price variances accounted for
the remaining $10.2 million. Oil production increased 38% in 3Q10
compared to 3Q09 while gas production declined 35% versus 3Q09.
Average realized oil prices were $73.18 per barrel in 3Q10 versus
$64.60 per barrel in 3Q09, and average realized gas prices were
$4.56 per Mcf in 3Q10 versus $3.79 per Mcf in 3Q09.
- Oil and gas production per BOE (barrel
of oil equivalent) increased by 4% in 3Q10 as compared to 3Q09. Oil
production for 3Q10 increased 38% to 915,000 barrels, or 9,946
barrels per day, as compared to 662,000 barrels, or 7,196 barrels
per day, for 3Q09 due primarily to added production from the
Company’s oil-prone drilling programs in the Permian Basin and the
Austin Chalk. Gas production for 3Q10 declined 35% to 2.5 Bcf, or
27,500 Mcf per day, as compared to 3.9 Bcf, or 42,391 Mcf per day,
for 3Q09 due primarily to a combination of normal production
declines from existing wells and the loss of production related to
the sale of certain properties in North Louisiana in June 2010 as
discussed below.
- In June 2010, the Company sold its
interest in 22 operated and 76 non-operated producing wells in
North Louisiana for net proceeds of $73.1 million. During 3Q09 the
sold wells produced 230 barrels of oil per day and 10,076 Mcf of
gas per day. After giving pro forma effect to the sale of these
properties on the reported production for 3Q09, oil and gas
production per BOE increased 19% as compared to a 4% unadjusted
increase in production.
- Loss on derivatives for 3Q10 was $4
million ($8 million non-cash mark-to-market loss and $4 million
realized gain on settled contracts) versus a gain in 3Q09 of $4.7
million ($10.6 million non-cash mark-to-market gain and $5.9
million realized loss on settled contracts). See accompanying
tables for additional information about the Company’s accounting
for derivatives.
- Exploration charges decreased $23.3
million in 3Q10 to $1.7 million compared to $25 million in 3Q09 due
primarily to the Company’s current emphasis on developmental
drilling.
Scheduled Conference Call
The Company will host a conference call to discuss these results
and other forward-looking items, November 3rd at 1:30 pm CT (2:30
pm ET). The dial-in conference number is: 800-901-5213, passcode
75748062. The replay will be available for one week at
888-286-8010, passcode 88716373.
To access the conference call via Internet webcast, please go to
the Investor Relations section of the Company’s website at
www.claytonwilliams.com and click on “Live Webcast.” Following the
live webcast, the call will be archived for a period of 90 days on
the Company’s website.
Clayton Williams Energy, Inc. is an independent energy company
located in Midland, Texas.
This release contains 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 or current facts, that address
activities, events, outcomes and other matters that we plan,
expect, intend, assume, believe, budget, predict, forecast,
project, estimate or anticipate (and other similar expressions)
will, should or may occur in the future are forward-looking
statements. These forward-looking statements are based on
management’s current belief, based on currently available
information, as to the outcome and timing of future events. The
Company cautions that its future natural gas and liquids
production, revenues, cash flows, liquidity, plans for future
operations, expenses, outlook for oil and natural gas prices,
timing of capital expenditures and other forward-looking statements
are subject to all of the risks and uncertainties, many of which
are beyond our control, incident to the exploration for and
development, production and marketing of oil and gas.
These risks include, but are not limited to, the possibility of
unsuccessful exploration and development drilling activities, our
ability to replace and sustain production, commodity price
volatility, domestic and worldwide economic conditions, the
availability of capital on economic terms to fund our capital
expenditures and acquisitions, our level of indebtedness, the
impact of the current economic recession on our business
operations, financial condition and ability to raise capital,
declines in the value of our oil and gas properties resulting in a
decrease in our borrowing base under our credit facility and
impairments, the ability of financial counterparties to perform or
fulfill their obligations under existing agreements, the
uncertainty inherent in estimating proved oil and gas reserves and
in projecting future rates of production and timing of development
expenditures, drilling and other operating risks, lack of
availability of goods and services, regulatory and environmental
risks associated with drilling and production activities, the
adverse effects of changes in applicable tax, environmental and
other regulatory legislation, and other risks and uncertainties are
described in the Company's filings with the Securities and Exchange
Commission. The Company undertakes no obligation to publicly update
or revise any forward-looking statements.
CLAYTON WILLIAMS ENERGY, INC. CONSOLIDATED
STATEMENTS OF OPERATIONS (Unaudited) (In thousands,
except per share)
Three Months Ended Nine Months Ended
September 30, September 30, 2010 2009
2010 2009 REVENUES Oil and gas sales $ 81,978 $
59,436 $ 237,938 $ 167,438 Natural gas services 397 1,639 1,352
4,578 Drilling rig services - - - 6,681 Gain on sales of assets
2,857 1,351 3,256
2,014 Total revenues 85,232 62,426
242,546 180,711 COSTS AND
EXPENSES Production 20,518 19,258 62,012 56,617 Exploration:
Abandonments and impairments 364 24,149 6,133 41,066 Seismic and
other 1,361 898 3,995 6,556 Natural gas services 297 1,344 951
3,966 Drilling rig services 123 904 1,204 10,901 Depreciation,
depletion and amortization 25,223 30,053 76,272 92,704 Impairment
of property and equipment 794 - 11,908 32,068 Accretion of
abandonment obligations 659 824 1,953 2,290 General and
administrative 8,730 4,012 22,786 14,796 Loss on sales of assets
and impairment of inventory 80 555
1,523 4,400 Total costs and expenses
58,149 81,997 188,737
265,364 Operating income (loss) 27,083
(19,571 ) 53,809 (84,653 ) OTHER
INCOME (EXPENSE) Interest expense (6,040 ) (6,526 ) (18,393
) (17,700 ) Gain (loss) on derivatives (3,995 ) 4,723 27,289
(14,537 ) Other 972 (76 ) 2,816 1,651
Total other income (expense) (9,063 ) (1,879 )
11,712 (30,586 ) Income (loss) before income
taxes 18,020 (21,450 ) 65,521 (115,239 ) Income tax
(expense) benefit (6,397 ) 7,850 (23,260 ) 42,171
NET INCOME (LOSS) 11,623 (13,600 ) 42,261 (73,068 )
Less income attributable to noncontrolling interest, net of tax
- - - (1,455 ) NET
INCOME (LOSS) attributable to Clayton Williams Energy, Inc. $
11,623 $ (13,600 ) $ 42,261 $ (74,523 ) Net
income (loss) per common share attributable to Clayton Williams
Energy, Inc. stockholders: Basic $ 0.96 $ (1.12 ) $ 3.48
$ (6.14 ) Diluted $ 0.96 $ (1.12 ) $ 3.48 $
(6.14 ) Weighted average common shares outstanding: Basic
12,146 12,144 12,146
12,136 Diluted 12,146 12,144
12,146 12,136
CLAYTON WILLIAMS ENERGY, INC. CONSOLIDATED BALANCE
SHEETS (In thousands) ASSETS
September 30, December 31, 2010 2009
(Unaudited)
CURRENT ASSETS
Cash and cash equivalents $ 22,004 $ 14,013 Accounts receivable:
Oil and gas sales 28,766 28,721 Joint interest and other, net 4,815
6,669 Affiliates 690 624 Inventory 45,080 43,068 Deferred income
taxes 168 1,362 Fair value of derivatives 14,239 - Assets held for
sale 7,411 7,411 Prepaids and other 2,724
1,729 125,897 103,597 PROPERTY
AND EQUIPMENT Oil and gas properties, successful efforts method
1,631,453 1,579,664 Natural gas gathering and processing systems
18,401 17,816 Contract drilling equipment 50,158 41,533 Other
20,196 16,550 1,720,208 1,655,563 Less
accumulated depreciation, depletion and amortization
(1,008,119 ) (985,517 ) Property and equipment, net
712,089 670,046 OTHER ASSETS Debt issue
costs, net 4,210 4,874 Fair value of derivatives 2,155 4,427 Other
1,836 1,660 8,201
10,961 $ 846,187 $ 784,604
LIABILITIES AND STOCKHOLDERS' EQUITY CURRENT
LIABILITIES Accounts payable: Trade $ 48,389 $ 47,211 Oil and gas
sales 26,218 18,063 Affiliates 1,015 1,097 Fair value of
derivatives - 5,907 Accrued liabilities and other 13,910
11,995 89,532 84,273
NON-CURRENT LIABILITIES Long-term debt 385,000
395,000 Deferred income taxes 76,016 54,065 Other 41,103
38,991 502,119 488,056
STOCKHOLDERS' EQUITY Preferred stock, par value $.10
per share - - Common stock, par value $.10 per share 1,215 1,215
Additional paid-in capital 152,051 152,051 Retained earnings
101,270 59,009 Total stockholders' equity
254,536 212,275 $ 846,187
$ 784,604
CLAYTON WILLIAMS ENERGY, INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited) (In thousands)
Three Months Ended Nine Months Ended
September 30, September 30, 2010 2009
2010 2009 CASH FLOWS FROM OPERATING
ACTIVITIES Net income (loss) $ 11,623 $ (13,600 ) $ 42,261 $
(73,068 ) Adjustments to reconcile net income (loss) to cash
provided by operating activities: Depreciation, depletion and
amortization 25,223 30,053 76,272 92,704 Impairment of property and
equipment 794 - 11,908 32,068 Exploration costs 364 24,149 6,133
41,066 (Gain) loss on sales of assets and impairment of inventory,
net (2,777 ) (796 ) (1,733 ) 2,386 Deferred income tax expense
(benefit) 6,397 (7,850 ) 23,260 (42,171 ) Non-cash employee
compensation 2,987 326 8,066 953 Unrealized (gain) loss on
derivatives 7,997 (10,593 ) (17,874 ) 8,314 Amortization of debt
issue costs 400 539 1,174 1,163 Accretion of abandonment
obligations 659 824 1,953 2,290 Changes in operating working
capital: Accounts receivable (3,491 ) 2,198 1,743 12,777 Accounts
payable 8,650 (9,449 ) 5,247 (26,075 ) Other (1,335 )
12,536 (4,242 ) 15,800 Net cash
provided by operating activities 57,491 28,337
154,168 68,207 CASH FLOWS
FROM INVESTING ACTIVITIES Additions to property and equipment
(73,113 ) (30,726 ) (208,641 ) (99,808 ) Proceeds from sales of
assets 2,659 1,439 75,670 2,109 Change in equipment inventory
(4,375 ) (13,274 ) (3,075 ) (25,868 ) Other (33 ) (12
) (131 ) (109 ) Net cash used in investing activities
(74,862 ) (42,573 ) (136,177 ) (123,676
) CASH FLOWS FROM FINANCING ACTIVITIES Proceeds from
long-term debt 29,000 50,700 - 75,900 Repayments of long-term debt
- (30,000 ) (10,000 ) (39,375 ) Proceeds from exercise of stock
options - - - 152
Net cash provided by (used in) financing activities
29,000 20,700 (10,000 ) 36,677
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS
11,629 6,464 7,991 (18,792 ) CASH AND CASH EQUIVALENTS
Beginning of period 10,375 15,943 14,013 41,199
End of period $ 22,004 $ 22,407 $
22,004 $ 22,407
CLAYTON WILLIAMS ENERGY,
INC. COMPUTATION OF EBITDAX (Unaudited) (In
thousands)
EBITDAX is presented as a supplemental non-GAAP financial
measure because of its wide acceptance by financial analysts,
investors, debt holders, banks, rating agencies and other financial
statement users as an indication of an entity's ability to meet its
debt service obligations and to internally fund its exploration and
development activities.
The Company defines EBITDAX as net income (loss) before interest
expense, income taxes, exploration costs, (gain)/loss on sales of
assets and impairment of inventory and all non-cash items in the
Company's statements of operations, including depreciation,
depletion and amortization, impairment of property and equipment,
accretion of abandonment obligations, certain employee compensation
and changes in fair value of derivatives. EBITDAX is not an
alternative to net income (loss) or cash flow from operating
activities, or any other measure of financial performance presented
in conformity with GAAP.
The following table reconciles net income
(loss) to EBITDAX:
Three Months Ended
Nine Months Ended
September 30, September 30, 2010
2009 2010 2009 Net income (loss)
$ 11,623 $ (13,600 ) $ 42,261 $ (73,068 ) Interest expense 6,040
6,526 18,393 17,700 Income tax (benefit) expense 6,397 (7,850 )
23,260 (42,171 ) Exploration: Abandonments and impairments 364
24,149 6,133 41,066 Seismic and other 1,361 898 3,995 6,556 (Gain)
loss on sales of assets and impairment of inventory (2,777 ) (796 )
(1,733 ) 2,386 Depreciation, depletion and amortization 25,223
30,053 76,272 92,704 Impairment of property and equipment 794 -
11,908 32,068 Accretion of abandonment obligations 659 824 1,953
2,290 Non-cash employee compensation 2,987 326 8,066 953 Non-cash
changes in fair value of derivatives 7,997 (10,593 ) (17,874 )
8,314 $ 60,668 $ 29,937 $
172,634 $ 88,798
Clayton Williams Energy,
Inc. Summary Production and Price Data
(Unaudited)
Three Months Ended Nine Months Ended September
30, September 30, 2010 2009 2010
2009 Average Daily Production: Oil
(Bbls): Permian Basin 6,092 3,526 5,469 4,010 Austin Chalk (Trend)
3,044 2,585 2,827 2,821 North Louisiana - 230
94
257 South Louisiana 727 773 596 624 Other 83
82
80
87 Total 9,946 7,196
9,066 7,799 Natural Gas
(Mcf): Permian Basin 13,931 14,374 13,702 15,157 Austin Chalk
(Trend) 2,325 2,306 2,222 2,580 North Louisiana
-
10,076
4,790
12,007 South Louisiana 5,650 10,755 6,024 10,342 Cotton Valley Reef
Complex 3,708 3,916 3,770 3,989 Other
1,886
964
1,232
1,233 Total 27,500 42,391
31,740 45,308 Natural gas
liquids (Bbls): Permian Basin 535 246 388 241 Austin Chalk (Trend)
258 288 238 296 North Louisiana
-
26
10
21 South Louisiana 119 116 95 73 Other
66
9
27
10 Total 978 685
758 641
Total Production:
Oil (MBbls) 915 662 2,475 2,129 Natural Gas (MMcf) 2,530 3,900
8,665 12,369 Natural gas liquids (MBbls) 90 63
207 175 Total (MBOE) 1,427 1,375
4,126 4,366
Average Realized Prices (a): Oil
($/Bbl) $ 73.18 $ 64.60 $ 74.39 $ 52.10
Gas ($/Mcf) $ 4.56 $ 3.79 $ 5.21 $ 4.11
Natural gas liquids ($/Bbl) $ 36.88 $ 31.89 $ 40.38
$ 26.70
Gain (Loss) on settled derivative
contracts (a): ($ in thousands, except per unit) Oil: Net
realized loss $ (227 ) $ (8,861 ) $ (3,098 ) $ (13,701 ) Per unit
produced ($/Bbl) $ (0.25 ) $ (13.39 ) $ (1.25 ) $ (6.44 )
Gas: Net realized gain $ 4,230 $ 2,992 $ 12,514 $ 7,478 Per unit
produced ($/Mcf) $ 1.67 $ 0.77 $ 1.44 $ 0.60
(a) Hedging gains/losses are only included in the determination of
the Company's average realized prices if the underlying derivative
contracts are designated as cash flow hedges under applicable
accounting standards. The Company did not designate any of its 2010
or 2009 derivative contracts as cash flow hedges. This means that
the Company's derivatives for 2010 and 2009 have been
marked-to-market through its statement of operations as other
income/expense instead of through accumulated other comprehensive
income on the Company's balance sheet. This also means that all
realized gains/losses on these derivatives are reported in other
income/expense instead of as a component of oil and gas sales.
Clayton Williams Energy, Inc. Summary of Open
Commodity Derivatives (Unaudited)
The following summarizes information concerning the
Company’s net positions in open commodity derivatives applicable to
periods subsequent to September 30, 2010.
Oil
Gas Swaps: Bbls Price MMBtu
(a) Price Production Period: 4th Quarter 2010 480,000
$ 76.24 1,680,000 $ 6.80
2011
2,376,000 $ 83.75 6,420,000 $ 7.07
2012
570,000 $ 87.60 - $ - 3,426,000 8,100,000
____
(a) One MMBtu equals one Mcf at a Btu factor of 1,000.
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