HOUSTON, July 22 /PRNewswire-FirstCall/ -- Newfield Exploration
Company (NYSE:NFX) today reported its unaudited second quarter 2009
financial and operating results. Newfield will be hosting a
conference call at 8:30 a.m. (CDT) on July 23. To participate in
the call, dial 719-325-4798 or listen through the website at
http://www.newfield.com/. "Our second quarter results show the
diligent efforts of our employees to lower costs and improve
margins throughout our focus areas," said President & CEO Lee
K. Boothby. "We are seeing cost reductions throughout our
operations. A combination of improving efficiencies in drilling and
completions, falling service costs and a strong hedge position in
2009-2010 provides us with an advantage in today's challenging
environment. Our production volumes are strong. In fact, we expect
to be in the top half of our guidance range for 2009 AND we intend
to continue deferring completions in the Woodford, as well as defer
completions on the remainder of our planned Granite Wash wells in
2009. "We are intensely focused on how we are allocating capital in
our business units today, ensuring that dollars are flowing to the
areas with the best returns and the highest growth prospects. We
intend to meet our production targets in 2009 and are confident
that our portfolio will allow us to grow production at similar
percentage levels, within cash flow, in 2010-11." Second Quarter
2009 For the second quarter of 2009, Newfield recorded a net loss
of $39 million, or $0.30 per diluted share (all per share amounts
are on a diluted basis). The loss reflects a net unrealized loss on
commodity derivatives of $322 million ($208 million after-tax), or
$1.58 per share. Without the effect of this item, net income for
the second quarter of 2009 would have been $169 million, or $1.28
per share. Revenues in the second quarter of 2009 were $287
million. Net cash provided by operating activities before changes
in operating assets and liabilities was $417 million. See
"Explanation and Reconciliation of Non-GAAP Financial Measures"
found after the financial statements in this release. Newfield's
production in the second quarter of 2009 was 65 Bcfe, an increase
of 12% over the second quarter of 2008. An additional 1 Bcfe was
produced in Malaysia during the second quarter of 2009 but was not
lifted due to timing of liftings. Capital expenditures in the
second quarter of 2009 were $300 million. Highlights --
Mid-Continent Update - Gross operated production from the
Mid-Continent division has been running ahead of beginning of the
year expectations, primarily due to increased production from the
Granite Wash play. Current gross production from the Mid-Continent
is 400 MMcfe/d, or 292 MMcfe/d net. -- Horizontal Drilling Success
at Stiles Ranch - Newfield's first seven horizontal wells in the
Granite Wash play had an average initial production rate of 22
MMcfe/d. All of the wells to date have been drilled in the Stiles
Ranch field, located in Wheeler County, Texas. In the second
quarter of 2009, Newfield increased its activity in the field and
is today running three operated drilling rigs, all drilling
horizontal wells. Newfield has an approximate 80% working interest
in Stiles Ranch and substantially all of the acreage is
held-by-production. A complete update on the Granite Wash
activities can be found in a separate news release issued earlier
today. -- Woodford Shale - Since the beginning of the year,
Newfield has released three operated rigs in the Woodford. The
Company now has 10 operated rigs running under term contracts, with
four of the remaining rigs rolling off of term contracts in the
second half of 2009. The timing of rig contract expirations and the
fact that more than 90% of the Company's 165,000 net acres are now
held-by-production provides flexibility. Due to the recent weakness
in natural gas prices, Newfield has been intentionally slowing its
pace of new well completions. Newfield has an inventory of about 25
wells that have been drilled but not completed. The timing of these
completions largely depends on natural gas prices. Gross operated
production in the Woodford is approximately 240 MMcfe/d, or about
equal to the first quarter 2009 exit rate. -- Woodford Gas Sales
Now Flowing Through Mid-Continent Express - Last week, Newfield
initiated firm gas sales through the new Arkoma Connector and into
the Mid-Continent Express pipeline. Today, 100% of the Company's
Woodford gas is being sold under firm transportation agreements.
Newfield's realized prices for Mid-Continent properties are
expected to improve to 75-85% of the Henry Hub Index as the Company
utilizes firm transportation agreements that provide guaranteed
pipeline capacity at a fixed price to move its natural gas
production to the Perryville, Louisiana markets. -- Deepwater Gulf
of Mexico Update - Newfield recently announced two discoveries in
the deepwater Gulf of Mexico -- Pyrenees and Winter. Since the
beginning of 2008, Newfield has drilled seven successful wells out
of eight exploration attempts in the deepwater Gulf and now has
seven deepwater developments underway, providing significant future
production growth. -- Pyrenees Sidetrack Underway - Located at
Garden Banks (GB) Block 293 in approximately 2,100' of water,
Pyrenees encountered approximately 125' of net hydrocarbon pay in
three separate intervals. Newfield and its partners recently
contracted a deepwater rig and are in the process of sidetracking
the well to test both shallower and deeper objectives. Newfield
operates the development with a 40% working interest. -- Additional
Prospects Around Pyrenees Added Through Recent GOM Lease Sale - In
the most recent GOM lease sale, Newfield picked up four additional
lease blocks associated with the "Pyrenees Complex." New prospects
include Mastiff (GB 338, 382) and Saluki (GB 381, 425) where
Newfield operates with an 85% and a 100% working interest,
respectively. The Company is in the process of selling down a
portion of its interest in these prospects on a promoted basis.
Exploratory drilling could occur as early as 2010. -- Winter -
Winter (GB 605) is located in approximately 3,400' of water. The
well encountered approximately 44' of net hydrocarbon pay in two
sands and was temporarily abandoned. Partners are considering
various development options, with first production anticipated in
2011. Newfield is the operator with a 30% working interest. --
Monument Butte Update - Gross oil production from Monument Butte,
located in the Uinta Basin of Utah, is about 16,000 BOPD.
Differentials have narrowed recently to $12-$13 per barrel below
WTI (including transportation expense). Newfield is running a
three-rig program in the Monument Butte field today and plans to
add a fourth operated rig in the third quarter of 2009. The
Monument Butte field area covers approximately 180,000 gross acres,
substantially all held by production. -- Williston Basin Update
-The Company has approximately 500,000 net acres, with nearly
200,000 acres in prospective development areas. Newfield has
drilled 11 successful oil wells in the North Dakota portion of the
Williston Basin and gross operated production is about 4,000 BOEPD.
Newfield is currently running one operated rig in the basin. The
most recent completion was the Moberg 1-29H well, located in
McKenzie County, North Dakota. The well had initial production of
1,200 BOEPD. Newfield operates the well with a 72% working
interest. Newfield Exploration Company is an independent crude oil
and natural gas exploration and production company. The Company
relies on a proven growth strategy of growing reserves through an
active drilling program and select acquisitions. Newfield's
domestic areas of operation include the Mid-Continent, the Rocky
Mountains, onshore Texas and the Gulf of Mexico. The Company has
international operations in Malaysia and China. **This release
contains forward-looking information. All information other than
historical facts included in this release, such as information
regarding estimated or anticipated third quarter 2009 results,
estimated 2009 capital expenditures, cash flow, production and cost
reductions, drilling and development plans and the timing of
activities, is forward-looking information. Although Newfield
believes that these expectations are reasonable, this information
is based upon assumptions and anticipated results that are subject
to numerous uncertainties and risks. 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 refining capacity for
the crude oil Newfield produces from its Monument Butte field in
Utah, the availability and cost of capital resources, labor
conditions and severe weather conditions (such as hurricanes). In
addition, the drilling of oil and gas wells and the production of
hydrocarbons are subject to governmental regulations and operating
risks. For information, contact: Investor Relations: Steve Campbell
(281) 847-6081 Media Relations: Keith Schmidt (281) 674-2650 Email:
2Q09 Actual Results 2Q09 Actual Domestic Int'l Total
Production/Liftings Natural gas - Bcf 45.2 - 45.2 Oil and
condensate - MMBbls 1.9 1.3 3.2 Total Bcfe 56.4 8.2 64.6 Average
Realized Prices (Note 1) Natural gas - $/Mcf $6.21 $- $6.21 Oil and
condensate - $/Bbl $97.15 $47.29 $76.09 Mcf equivalent - $/Mcfe
$8.21 $7.86 $8.16 Operating Expenses: Lease operating Recurring
($MM) (Note 2) $40.0 $11.5 $51.5 per/Mcfe $0.71 $1.40 $0.80 Major
(workovers, repairs, etc.) ($MM) $5.1 $0.3 $5.4 per/Mcfe $0.09
$0.04 $0.08 Production and other taxes ($MM) $11.8 $2.8 $14.6
per/Mcfe $0.21 $0.34 $0.23 General and administrative (G&A),
net ($MM) $32.0 $1.8 $33.8 per/Mcfe $0.57 $0.22 $0.52 Capitalized
internal costs ($MM) $(18.3) per/Mcfe $(0.28) Interest expense
($MM) $31.8 per/Mcfe $0.49 Capitalized interest ($MM) $(12.1)
per/Mcfe $(0.19) Note 1: Average realized prices include the
effects of hedging contracts. If the effects of these contracts
were excluded, the average realized price for total gas would have
been $2.85 per Mcf and the total oil and condensate average
realized price would have been $48.42 per barrel. Note 2:
International recurring lease operating expenses in the second
quarter of 2009 included a $1 million ($0.12 per Mcfe) benefit
associated with a prior period adjustment on properties operated by
others. 3Q09 Estimates 3Q09 Estimates Domestic Int'l Total
Production/Liftings( ) Natural gas - Bcf 43.5 - 48.9 - 43.5 - 48.9
Oil and condensate - MMBbls 1.5 - 1.6 1.7 - 1.9 3.2 - 3.5 Total
Bcfe 52.5 - 58.5 10.4 - 11.5 62.9 - 70.0 Average Realized Prices
Natural gas - $/Mcf Note 1 Oil and condensate - Note 2 Note 3 $/Bbl
Mcf equivalent - $/Mcfe Operating Expenses: Lease operating
Recurring ($MM) $34.0 - $38.0 $21.7 - $24.0 $55.7 - $62.0 per/Mcfe
$0.64 - $0.65 $2.08 - $2.10 $0.88 - $0.89 Major (workover, repairs,
etc.) ($MM) $4.0 - $6.0 $0.9 - $1.0 $4.9 - $7.0 per/Mcfe $0.08 -
$0.10 $0.09 - $0.10 $0.08 - $0.10 Production and other taxes ($MM)
(Note 4) $14.3 - $15.9 $9.6 - $10.6 $23.9 - $26.5 per/Mcfe $0.27 -
$0.28 $0.92 - $0.93 $0.37 - $0.39 General and administrative
(G&A), net ($MM) $29.9 - $33.0 $1.4 - $1.6 $31.3 - $34.6
per/Mcfe $0.56 - $0.57 $0.13 - $0.14 $0.49 - $0.50 Capitalized
internal costs ($MM) $(18.5 - $20.5) per/Mcfe $(0.29 - $0.30)
Interest expense ($MM) $29.9 - $33.1 per/Mcfe $0.47 - $0.48
Capitalized interest ($MM) $(11.4 - $12.6) per/Mcfe $(0.18 - $0.19)
Tax rate (%) (Note 5) 36% - 38% Income taxes (%) Current 14% - 16%
Deferred 84% - 86% Note 1: Gas prices in the Mid-Continent, after
basis differentials, transportation and handling charges, typically
average 70 - 80% of the Henry Hub Index. Beginning in the third
quarter of 2009, our realized prices for Mid-Continent properties
should improve to 75-85% of the Henry Hub Index as we begin to
utilize our agreements that provide guaranteed pipeline capacity at
a fixed price to move this natural gas production to the Perryville
markets. Gas prices in the Gulf Coast, after basis differentials,
transportation and handling charges, are expected to average $0.50
- $0.75 per MMBtu less than the Henry Hub Index. Note 2: Oil prices
in the Gulf Coast typically average 90 - 95% of NYMEX WTI price.
Rockies oil prices average about $12 - $14 per barrel below WTI.
Oil production from the Mid-Continent typically averages 85 - 90%
of WTI. Note 3: Oil in Malaysia typically sells at a slight
discount to Tapis, or about 85-90% of WTI. Oil production from
China typically sells at $6 - $8 per barrel below WTI. Note 4:
Guidance for production taxes determined using $65/Bbl oil and
$4.50/MMBtu gas. Note 5: Tax rate applied to earnings excluding
unrealized gains or losses on commodity derivatives. CONSOLIDATED
STATEMENT OF INCOME For the For the (Unaudited, in millions, except
per Three Months Six Months share data) Ended June 30, Ended June
30, ------------- -------------- 2009 2008 2009 2008 ---- ---- ----
---- Oil and gas revenues $287 $691 $549 $1,207 ---- ---- ----
------ Operating expenses: Lease operating 57 58 128 117 Production
and other taxes 15 52 24 103 Depreciation, depletion and
amortization 137 166 296 323 General and administrative 34 37 66 69
Ceiling test writedown - - 1,344 - Other 5 - 7 - --- --- --- ---
Total operating expenses 248 313 1,865 612 --- --- ----- --- Income
(loss) from operations 39 378 (1,316) 595 Other income (expenses):
Interest expense (32) (28) (64) (47) Capitalized interest 12 13 26
27 Commodity derivative income (expense) (81) (652) 197 (973) Other
2 - 5 2 --- --- --- --- (99) (667) 164 (991) --- ---- --- ---- Loss
before income taxes (60) (289) (1,152) (396) Income tax benefit
(21) (45) (419) (88) --- --- ---- --- Net loss $(39) $(244) $(733)
$(308) ==== ===== ===== ===== Loss per share: Basic -- $(0.30)
$(1.89) $(5.66) $(2.39) ====== ====== ====== ====== Diluted --
$(0.30) $(1.89) $(5.66) $(2.39) ====== ====== ====== ======
Weighted average number of shares outstanding for basic loss per
share 130 129 129 129 Weighted average number of shares outstanding
for diluted loss per share * 130 129 129 129 * Had we recognized
net income for the three and six months ended June 30, 2009 and
2008, the weighted average number of shares outstanding for the
computation of diluted earnings per share would have increased by 2
million shares for the three and six months ended June 30, 2009 and
3 million shares for the three and six months ended June 30, 2008.
CONDENSED CONSOLIDATED BALANCE SHEET June 30, December 31,
(Unaudited, in millions) 2009 2008 ---- ---- ASSETS Current assets:
Cash and cash equivalents $38 $24 Derivative assets 549 663 Other
current assets 493 519 --- --- Total current assets 1,080 1,206
Property and equipment, net (full cost method) 4,789 5,758
Derivative assets 101 247 Other assets 88 94 -- -- Total assets
$6,058 $7,305 ====== ====== LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities $818 $1,085 ---- ------ Other liabilities 113
92 Long-term debt 2,292 2,213 Deferred taxes 288 658 --- --- Total
long-term liabilities 2,693 2,963 ----- ----- Commitments and
contingencies - - STOCKHOLDERS' EQUITY Common stock 1 1 Additional
paid-in capital 1,359 1,335 Treasury stock (33) (32) Accumulated
other comprehensive loss (11) (11) Retained earnings 1,231 1,964
----- ----- Total stockholders' equity 2,547 3,257 ----- -----
Total liabilities and stockholders' equity $6,058 $7,305 ======
====== CONDENSED CONSOLIDATED STATEMENT OF CASH FLOWS (Unaudited,
in millions) For the Six Months Ended June 30, -------- 2009 2008
---- ---- Cash flows from operating activities: Net loss $(733)
$(308) Adjustments to reconcile net loss to net cash provided by
operating activities: Depreciation, depletion and amortization 296
323 Deferred tax benefit (420) (113) Stock-based compensation 15 12
Ceiling test writedown 1,344 - Commodity derivative (income)
expense (197) 973 Cash receipts (payments) on derivative
settlements 459 (668) --- ---- 764 219 Changes in operating assets
and liabilities (52) (47) --- --- Net cash provided by operating
activities 712 172 --- --- Cash flows from investing activities:
Additions to oil and gas properties and other, net (790) (1,320)
Net redemptions of investments 14 48 -- -- Net cash used in
investing activities (776) (1,272) ---- ------ Cash flows from
financing activities: Net proceeds under credit arrangements 78 268
Net proceeds from issuance of senior subordinated notes - 592 Other
- 18 --- -- Net cash provided by financing activities 78 878 -- ---
Increase (decrease) in cash and cash equivalents 14 (222) Cash and
cash equivalents, beginning of period 24 250 -- --- Cash and cash
equivalents, end of period $38 $28 === === Explanation and
Reconciliation of Non-GAAP Financial Measures Earnings Stated
Without the Effects of Certain Items Earnings stated without the
effects of certain items is a non-GAAP financial measure. Earnings
without the effects of these items are presented because they
affect the comparability of operating results from period to
period. In addition, earnings without the effects of these items
are more comparable to earnings estimates provided by securities
analysts. A reconciliation of earnings for the second quarter of
2009 stated without the effects of certain items to net loss is
shown below: 2Q09 ---- (in millions) Net loss $(39) Net unrealized
loss on commodity derivatives (1) 322 Income tax adjustment for
above item (114) ---- Earnings stated without the effect of the
above item $169 ==== (1) The determination of "Net unrealized loss
on commodity derivatives" for the second quarter of 2009 is as
follows: 2Q09 ---- (in millions) Commodity derivative expense $(81)
Cash receipts on derivative settlements (248) Option premiums
associated with derivatives settled during the period 7 ----- Net
unrealized loss on commodity derivatives $(322) ===== Net Cash
Provided by Operating Activities Before Changes in Operating Assets
and Liabilities 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 (used in) operating activities as defined by generally
accepted accounting principles. A reconciliation of net cash
provided by operating activities before changes in operating assets
and liabilities to net cash provided by operating activities is
shown below: 2Q09 ---- (in millions) Net cash provided by operating
activities $363 Net change in operating assets and liabilities 54
---- Net cash provided by operating activities before changes in
operating assets and liabilities $417 ==== DATASOURCE: Newfield
Exploration Company CONTACT: Investor Relations, Steve Campbell,
+1-281-847-6081, or Media Relations, Keith Schmidt,
+1-281-674-2650, , both of Newfield Exploration Company Web Site:
http://www.newfield.com/
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