Newfield Announces Second Quarter Results** HOUSTON, July 27
/PRNewswire-FirstCall/ -- Newfield Exploration Company (NYSE:NFX)
today announced its financial and operating results for the second
quarter of 2004. A conference call to discuss the results is
planned for 8:30 a.m. (CDT), Wednesday, July 28. To participate in
the call, dial 719-457-2665. A listen-only broadcast will also be
provided over the Internet. Simply go to the Investor Relations
section at http://www.newfld.com/ . Second Quarter 2004 For the
second quarter of 2004, Newfield reported net income of $67.4
million, or $1.18 per share (all per share amounts are on a diluted
basis). Stated without the effect of $1.3 million ($0.8 million
after-tax), or $0.01 per share, of income related to unrealized
commodity derivative transactions, net income for the second
quarter was $66.6 million, or $1.17 per share. Revenues in the
second quarter of 2004 were $282.7 million. Net cash provided by
operating activities before changes in operating assets and
liabilities was $185.1 million in the second quarter of 2004. See
Explanation and Reconciliation of Non-GAAP Financial Measures.
Newfield's results for the second quarter of 2004 compare favorably
to the same period of the prior year. Net income from continuing
operations in the second quarter of 2003 was $53.1 million, or
$0.95 per share. Net income from continuing operations in the
second quarter of 2003 was impacted by a $10.5 million one-time
charge ($6.8 million after tax), related to the redemption of all
of the outstanding 6 1/2% convertible trust preferred securities
(QUIPS). Revenues in the second quarter of 2003 were $255.6
million. Net cash provided by continuing operating activities
before changes in operating assets and liabilities was $178.9
million in the second quarter of 2003. Newfield's production in the
second quarter of 2004 of 56.0 billion cubic feet equivalent (Bcfe)
remained flat when compared to the second quarter 2003 production
of 56.2 Bcfe. The following tables detail production and average
realized prices for the second quarter of 2004 and 2003. Production
2Q04 2Q03 % Change Natural gas (Bcf) 47.5 46.8 1% Oil and
condensate (MMBbls) 1.4 1.6 (10%) Total (Bcfe) 56.0 56.2 ---
Average Realized Prices+ 2Q04 2Q03 % Change Natural gas (per Mcf)
$4.89 $4.50 9% Oil and condensate (per Bbl) 34.18 27.54 24% Natural
gas equivalent (per Mcfe) 5.02 4.51 11% +Prices shown are net of
all applicable transportation expenses, which reduced the realized
price of natural gas by $0.03 and $0.02 per Mcf for the three
months ended June 30, 2004 and 2003, respectively. The realized
price of oil and condensate was reduced by $0.46 and $0.45 per Bbl
for the three months ended June 30, 2004 and 2003, respectively.
Average realized prices also include the effects of hedging other
than our three-way collar contracts, which do not qualify for hedge
accounting under SFAS No. 133. Had we included the realized loss on
our three-way collar contracts, our average realized price for
natural gas would have been $4.82 per Mcf and our average realized
price for oil and condensate would have been $31.95 per Bbl for the
second quarter of 2004. The settlement of our three-way contracts
had no impact on our realized prices for the second quarter of
2003. We did not enter into any three-way collar contracts prior to
August 2003. Stated on a unit of production basis, Newfield's lease
operating expense (LOE) in the second quarter of 2004 was $0.52 per
Mcfe compared to LOE from continuing operations of $0.48 per Mcfe
in the same period of 2003. Production taxes in the second quarter
of 2004 increased to $0.16 per Mcfe compared to production taxes
from continuing operations of $0.13 per Mcfe in the same period of
2003. DD&A expense in the second quarter of 2004 was $1.88 per
Mcfe compared to DD&A expense from continuing operations of
$1.76 per Mcfe in the same period of 2003. G&A expense
(including stock compensation) in the second quarter of 2004 was
$0.34 per Mcfe compared to G&A expense from continuing
operations of $0.27 in the same period of 2003. G&A expense in
the second quarter of 2004 is net of capitalized direct internal
costs of $9.2 million compared to $7.4 million in the second
quarter of 2003. Capital expenditures in the second quarter of 2004
were $236 million. Year-to-Date 2004 For the first six months of
2004, Newfield posted net income of $145.3 million, or $2.55 per
share. Revenues for the first half of 2004 were $588.1 million.
This compares to net income from continuing operations of $112.4
million, or $2.02 per share, on revenues of $523.4 million for the
first half of 2003. Net cash provided by continuing operating
activities before changes in operating assets and liabilities was
$393.2 million in the first half of 2004 compared to $353.3 million
in the same period of 2003. See Explanation and Reconciliation of
Non-GAAP Financial Measures. Production volumes for the first half
of 2004 increased 4% above the same period last year. The Company
produced 113.3 Bcfe in the first six months of 2004 compared to
production from continuing operations of 109.3 Bcfe in the first
six months of the prior year. The following tables detail
production and average realized prices for the first half of 2004
and 2003: Production 1H04 1H03 % Change Natural gas (Bcf) 95.5 90.8
5% Oil and condensate (MMBbls) 3.0 3.1 (4%) Total (Bcfe) 113.3
109.3 4% Average Realized Prices+ 1H04 1H03 % Change Natural gas
(per Mcf) $5.10 $4.77 7% Oil and condensate (per Bbl) 32.87 28.27
16% Natural gas equivalent (per Mcfe) 5.16 4.76 8% +Prices shown
are net of all applicable transportation expenses, which reduced
the realized price of natural gas by $0.02 per Mcf and the realized
price of oil and condensate by $0.39 per Bbl for the first half of
both years. Average realized prices include the effects of hedging
other than our three- way collar contracts, which do not qualify
for hedge accounting under SFAS No. 133. Had we included the
realized loss on our three-way contracts our average realized price
for natural gas would have been $5.06 per Mcf and our average
realized price for oil and condensate would have been $31.80 per
Bbl for the six months ended June 30, 2004. The settlement of our
three-way contracts had no impact on our realized prices for the
first half of 2003. We did not enter into any three-way collar
contracts prior to August 2003. In the first half of 2004, LOE,
stated on a unit of production basis, averaged $0.52 per Mcfe,
compared to LOE from continuing operations of $0.50 per Mcfe in the
same period of 2003. Production taxes in the first half of 2004
decreased to $0.15 per Mcfe compared to production taxes from
continuing operations of $0.16 per Mcfe in the same period of 2003.
DD&A expense in the first half of 2004 was $1.86 per Mcfe
compared to DD&A expense from continuing operations of $1.76
per Mcfe in the same period of 2003. G&A expense (including
stock compensation) in the first half of 2004 was $0.33 per Mcfe
compared to G&A expense from continuing operations of $0.29 per
Mcfe in the prior year. G&A expense in the first half of 2004
is net of capitalized direct internal costs of $16.0 million
compared to $14.2 million in the first half of 2003. Capital
expenditures in the first half of 2004 totaled $389 million.
Explanation and Reconciliation of Non-GAAP Financial Measures
Earnings stated without the effect of unrealized commodity
derivative transactions, a non-GAAP financial measure, exclude
certain items that affect the comparability of operating results.
Earnings without the effect of these items are presented because
the amount of these items cannot be reasonably estimated and
because earnings without the effect of these items are more
comparable to earnings estimates provided by securities analysts.
Commodity derivative expense as stated in our consolidated
statement of income for the second quarter of 2004 includes an
unrealized increase in the fair value of our three-way collar
contracts of $0.9 million, a realized loss of $6.9 million for our
three-way collar contracts and a decrease in hedge ineffectiveness
of $0.4 million associated with our cash flow hedges. A
reconciliation of earnings stated without the effect of the
unrealized commodity derivative transactions to net income is shown
below: 2Q04 Net income $67.4 Unrealized commodity derivative
(income) expense (1.3) Income tax provision adjustment for above
item 0.5 Earnings stated without the effect of unrealized commodity
derivative transactions $66.6 Net cash provided by operating
activities before changes in operating assets and liabilities is
presented because of its acceptance as an indicator of an oil and
gas exploration and production company's ability to internally fund
exploration and development activities and to service or incur
additional debt. This measure should not be considered as an
alternative to net cash provided by operating activities as defined
by generally accepted accounting principles. A reconciliation of
net cash provided by operating activities from continuing
operations before changes in operating assets and liabilities to
net cash provided by operating activities from continuing
operations is shown below: 2Q04 2Q03 Net cash provided by operating
activities from continuing operations $195.5 $215.8 Less:
(Increase) decrease in operating assets and liabilities 10.4 36.9
Net cash provided by operating activities from continuing
operations before changes in operating assets and liabilities
$185.1 $178.9 1H04 1H03 Net cash provided by operating activities
from continuing operations $414.3 $276.8 Less: (Increase) decrease
in operating assets and liabilities 21.1 (76.5) Net cash provided
by operating activities from continuing operations before changes
in operating assets and liabilities $393.2 $353.3 Third Quarter
2004 Estimates Natural Gas Production and Pricing The Company's
natural gas production in the third quarter of 2004 is expected to
be 47 - 51 Bcf (510 - 560 MMcf/d). The price the Company realizes
for natural gas production from the Gulf of Mexico and onshore Gulf
Coast typically averages $0.15 - $0.20 less than Henry Hub Index
after basis differentials, transportation and handling charges.
Realized gas prices for our Mid-Continent properties typically
average $0.70 - $0.80 less than Henry Hub Index after basis
differentials, transportation and handing charges. Hedging gains or
losses will affect price realizations. Crude Oil Production and
Pricing Oil production in the third quarter of 2004 is expected to
be 1.8 - 2.0 million barrels (19,000 - 21,000 BOPD). The price the
Company receives for Gulf Coast production has typically averaged
about $2 below the NYMEX West Texas Intermediate (WTI) price. Oil
production from the Mid-Continent has typically sold at a $1.00 -
$1.50 per barrel discount to WTI. Hedging gains or losses will
affect price realizations. Lease Operating and Other Expenses LOE
is expected to be $43 - $48 million ($0.72 - $0.80 per Mcfe) in the
third quarter of 2004. Production taxes in the third quarter of
2004 are expected to be $12 - $14 million ($0.20 - $0.24 per Mcfe).
These expenses vary and are subject to impact from, among other
things, production volumes and commodity pricing, tax rates,
service costs, the costs of goods and materials and workover
activities. General and Administrative Expense G&A expense for
the third quarter of 2004 is expected to be $17 - $19 million
($0.29 - $0.32 per Mcfe), net of capitalized direct internal costs.
Capitalized G&A expense is expected to be $6 - $7 million.
G&A expense includes stock and incentive compensation expense.
Incentive compensation expense depends largely on net income.
Interest Expense The non-capitalized portion of the Company's
interest expense for the third quarter of 2004 is expected to be $6
- $7 million ($0.10 - $0.11 per Mcfe). As of July 26, 2004,
borrowings under the Company's credit arrangements are $265
million. The remainder of long-term debt consists of three separate
issuances of notes that in the aggregate total $550 million in
principal amount. Capitalized interest for the third quarter of
2004 is expected to be about $5 - $7 million. Income Taxes
Including both current and deferred taxes, the Company expects its
consolidated income tax rate in the third quarter of 2004 to be
about 35 - 39%. About 35% of the tax provision is expected to be
deferred. The Company provides information regarding its
outstanding hedging positions in its annual report and quarterly
reports filed with the SEC and in its electronic publication --
@NFX. This publication can be found on Newfield's web page at
http://www.newfld.com/ . Through the web page, you may elect to
receive @NFX through e-mail distribution. Newfield Exploration
Company is an independent crude oil and natural gas exploration and
production company. The Company relies on a proven growth strategy
that includes balancing acquisitions with drill bit opportunities.
Newfield's areas of operation include the Gulf of Mexico, the U.S.
onshore Gulf Coast, the Anadarko and Arkoma Basins and select
international ventures. **The statements set forth in this release
regarding estimated or anticipated third quarter results and
production volumes are forward looking and are based upon
assumptions and anticipated results that are subject to numerous
uncertainties. Actual results may vary significantly from those
anticipated due to many factors, including drilling results, oil
and gas prices, industry conditions, the prices of goods and
services, the availability of drilling rigs and other support
services, the availability of capital resources, labor conditions
and other factors set forth in the Company's Annual Report on Form
10-K for the year ended December 31, 2003. In addition, the
drilling of oil and gas wells and the production of hydrocarbons
are subject to governmental regulations and operating risks.
Newfield Exploration Company For information, contact: 363 N. Sam
Houston Parkway East, Ste. 2020 Steve Campbell Houston, TX 77060
(281) 847-6081 http://www.newfld.com/ CONSOLIDATED STATEMENT OF
INCOME (unaudited, in thousands, except share and per share data)
For the For the Three Months Ended Six Months Ended June 30, June
30, 2004 2003 2004 2003 Oil and gas revenues $ 282,737 $ 255,552 $
588,092 $ 523,443 Operating expenses: Lease operating 28,965 26,917
58,830 54,724 Production and other taxes 9,094 7,463 17,453 17,670
Transportation 1,942 1,859 3,382 3,422 Depreciation, depletion and
amortization 105,172 99,191 211,077 192,509 General and
administrative (A) 19,061 15,190 37,621 32,196 Gas sales obligation
settlement and redemption of securities --- 10,477 --- 20,475 Total
operating expenses 164,234 161,097 328,363 320,996 Income from
operations 118,503 94,455 259,729 202,447 Other income (expenses):
Interest expense (11,935) (14,982) (24,467) (31,668) Capitalized
interest 4,388 3,899 8,323 7,718 Dividends on convertible preferred
securities of Newfield Financial Trust I --- (2,245) --- (4,581)
Commodity derivative expense* (5,594) (1,629) (17,835) (2,846)
Other 340 (9) 1,000 511 (12,801) (14,966) (32,979) (30,866) Income
from continuing operations before income taxes 105,702 79,489
226,750 171,581 Income tax provision 38,288 26,434 81,428 59,180
Income from continuing operations 67,414 53,055 145,322 112,401
Loss from discontinued operations, net of tax --- (7,240) ---
(8,020) Income before cumulative effect of change in accounting
principle 67,414 45,815 145,322 104,381 Cumulative effect of change
in accounting principle, net of tax** --- --- --- 5,575 Net income
$ 67,414 $ 45,815 $ 145,322 $ 109,956 Earnings per share: Basic
Income from continuing operations $ 1.20 $ 1.00 $ 2.59 $ 2.13 Loss
from discontinued operations --- (0.14) --- (0.15) Cumulative
effect of change in accounting principle, net of tax** --- --- ---
0.11 Net income $ 1.20 $ 0.86 $ 2.59 $ 2.09 Diluted Income from
continuing operations $ 1.18 $ 0.95 $ 2.55 $ 2.02 Loss from
discontinued operations --- (0.13) --- (0.14) Cumulative effect of
change in accounting principle, net of tax** --- --- --- 0.10 Net
income $ 1.18 $ 0.82 $ 2.55 $ 1.98 Weighted average number of
shares outstanding for basic earnings per share 56,114 53,468
56,019 52,679 Weighted average number of shares outstanding for
diluted earnings per share 57,029 57,701 56,884 56,956 (A) Includes
non-cash stock compensation of $969 and $807 for the three months
June 30, 2004 and 2003, respectively, and $1,960 and $1,486 for the
six months ended June 30, 2004 and 2003, respectively. * Associated
with SFAS No. 133. ** Associated with the adoption of SFAS No. 143.
PRODUCTION DATA FROM CONTINUING OPERATIONS For the For the Three
Months Ended Six Months Ended June 30, June 30, 2004 2003 2004 2003
Average daily production: Oil and condensate (Bbls) 15,629 17,356
16,312 17,104 Natural gas (Mcf) 521.4 513.8 524.9 501.4 Average
realized price: Oil and condensate (Bbls) $ 34.18 $ 27.54 $ 32.87 $
28.27 Natural gas (Mcf) $ 4.89 $ 4.50 $ 5.10 $ 4.77 CONDENSED
CONSOLIDATED BALANCE SHEET (Unaudited, in thousands of dollars)
June 30, Dec. 31, 2004 2003 ASSETS Current assets: Cash and cash
equivalents $ 27,853 $ 15,347 Accounts receivable, oil and gas
184,359 134,774 Inventories 3,664 553 Derivative assets* 12,031
13,786 Deferred taxes 25,431 12,893 Other current assets 43,371
61,563 Total current assets 296,709 238,916 Oil and gas properties,
net (full cost method) 2,601,795 2,418,500 Floating production
system and pipelines 35,000 35,000 Furniture, fixtures and
equipment, net 5,369 5,875 Derivative assets* 3,228 2,223 Other
assets 17,644 16,197 Goodwill 16,378 16,378 Total assets $
2,976,123 $ 2,733,089 LIABILITIES AND STOCKHOLDERS' EQUITY Current
liabilities $ 349,284 $ 255,522 Derivative liabilities* 81,693
44,696 Total current liabilities 430,977 300,218 Other liabilities
13,040 13,203 Derivative liabilities* 13,190 13,244 Long-term debt
579,559 643,459 Asset retirement obligation** 158,283 151,548
Deferred taxes 267,994 242,839 Total long-term liabilities
1,032,066 1,064,293 Commitments and contingencies --- ---
STOCKHOLDERS' EQUITY Common stock 576 571 Additional paid-in
capital 811,422 796,256 Treasury stock (27,081) (26,679) Unearned
compensation (9,664) (10,912) Accumulated other comprehensive
income (loss): Foreign currency translation adjustment 1,124 851
Commodity derivatives* (43,538) (26,428) Minimum pension liability
(833) (833) Retained earnings 781,074 635,752 Total stockholders'
equity 1,513,080 1,368,578 Total liabilities and stockholders'
equity $ 2,976,123 $ 2,733,089 * Associated with SFAS No. 133. **
Associated with SFAS No. 143. CONDENSED CONSOLIDATED STATEMENT OF
CASH FLOWS (Unaudited, in thousands of dollars) For the For the
Three Months Ended Six Months Ended June 30, June 30, 2004 2003
2004 2003 Cash flows from operating activities: Net income $ 67,414
$ 45,815 $ 145,322 $ 109,956 Loss from discontinued operations, net
of tax --- 7,240 --- 8,020 Depreciation, depletion and amortization
105,172 99,191 211,077 192,509 Deferred taxes 12,781 13,710 25,340
23,600 Stock compensation 969 807 1,960 1,486 Commodity derivative
(income) expense* (1,251) 1,629 9,511 2,846 Gas sales obligation
settlement and redemption of securities --- 10,477 --- 20,475
Cumulative effect of change in accounting principle** --- --- ---
(5,575) 185,085 178,869 393,210 353,317 Changes in operating assets
and liabilities 10,448 36,897 21,051 (76,468) Net cash provided by
continuing activities 195,533 215,766 414,261 276,849 Net cash
provided by (used in) discontinued activities --- (3,911) --- 661
Net cash provided by operating activities 195,533 211,855 414,261
277,510 Cash flows from investing activities: Additions to oil and
gas properties (200,351) (105,857) (347,409) (228,519) Additions to
furniture, fixtures and equipment (957) (523) (1,659) (2,302) Net
cash used in continuing activities (201,308) (106,380) (349,068)
(230,821) Net cash used in discontinued activities --- (1,714) ---
(3,155) Net cash used in investing activities (201,308) (108,094)
(349,068) (233,976) Cash flows from financing activities: Proceeds
from borrowings under credit arrangements 253,000 275,000 385,500
1,019,000 Repayments of borrowings under credit arrangements
(244,000) (340,000) (446,500) (915,000) Repurchases of secured
notes --- (25,726) (2,895) (59,595) Deliveries under the gas sales
obligation --- --- --- (8,442) Proceeds from issuances of common
stock 7,694 136,957 11,321 137,683 Repayments of secured notes ---
--- --- (11,215) Gas sales obligation settlement --- --- ---
(62,017) Purchases of treasury stock (31) (23) (402) (362)
Redemption of trust preferred securities --- (148,448) ---
(148,448) Net cash provided by (used in) continuing activities
16,663 (102,240) (52,976) (48,396) Net cash provided by (used in)
discontinued activities --- --- --- --- Net cash provided by (used
in) financing activities 16,663 (102,240) (52,976) (48,396) Effect
of exchange rate changes on cash and cash equivalents 32 315 289
387 Increase (decrease) in cash and cash equivalents 10,920 1,836
12,506 (4,475) Cash and cash equivalents from continuing
operations, beginning of period 16,933 35,951 15,347 33,798 Cash
and cash equivalents from discontinued operations, beginning of
period --- 6,636 --- 15,100 Cash and cash equivalents, end of
period $ 27,853 $ 44,423 $ 27,853 $ 44,423 * Associated with SFAS
No. 133. ** Associated with the adoption of SFAS No. 143.
DATASOURCE: Newfield Exploration Company CONTACT: Steve Campbell of
Newfield Exploration Company, +1-281-847-6081, or Web site:
http://www.newfld.com/
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