Quicksilver Resources Reports Third-Quarter 2010 Results; Production Sets New Company Record
FORT WORTH, TX -- (Marketwire) -- 11/08/10 -- Quicksilver Resources Inc. (NYSE: KWK)
today reported net income of $21.8 million ($.13 per diluted share) in the
2010 third quarter as compared to income of $0.7 million ($.00 per diluted
share) in the prior-year period. Third-quarter 2010 adjusted net income,
a non-GAAP measure, was $28.7 million ($.17 per diluted share) as compared
to the 2009 period adjusted net income of $42.7 million ($.25 per diluted
share). Details of adjusted net income are included in the attached tables
of this news release.
Quicksilver achieved another record for average daily production in a
quarter, producing an average of more than 362 million cubic feet of
natural gas equivalents (MMcfe) per day in the third quarter of 2010, up
16.4% compared to approximately 311 MMcfe per day for the same period in
2009. Total production for the third quarter of 2010 was approximately
33.3 billion cubic feet of natural gas equivalents (Bcfe) compared to
approximately 28.6 Bcfe for the third quarter of 2009. Increased
production of dry gas from the company's Lake Arlington and Alliance
projects in the northern portion of its Fort Worth Basin acreage primarily
drove the production increase. The production volumes in the third quarter
of 2010 were comprised of approximately 78% natural gas, approximately 21%
natural gas liquids (NGLs) and approximately 1% crude oil and condensate.
In July, Quicksilver announced a definitive agreement to sell all of its
interests in Quicksilver Gas Services, the primary provider of midstream
services for our Fort Worth Basin operations, to Crestwood Holdings LLC for
$701 million in cash and up to an additional $72 million in earn-out
payments. That transaction was consummated on October 1, 2010. In
accordance with GAAP, Quicksilver will not treat this divestment as
discontinued operations because the divested entity will continue to
provide midstream services to Quicksilver. Therefore, the company's
results for the third quarter of 2010 include the consolidated results for
Quicksilver Gas Services. The company will present pro forma condensed
consolidated statement of operations, for this transaction, for the three
months and nine months ending September 30, 2010, in its Form 10-Q that is
expected to be filed later today.
Revenue and Costs
Sales of natural gas, NGLs and crude oil increased approximately 10% to
$218.2 million in the third quarter of 2010 as compared to $198.3 million
in the 2009 quarter. The increase was primarily due to greater production
volumes for natural gas offset in part by lower realized prices for natural
gas, NGLs and crude oil. The company's weighted-average realized price per
thousand cubic feet of natural gas equivalents (Mcfe) in the 2010 third
quarter was $6.55, down approximately 5.5% from the prior-year quarter.
Total production expense for the 2010 third quarter was $39.4 million
compared to $29.1 million in the prior-year quarter. The increase is
primarily associated with higher production volumes and increases for
saltwater disposal costs and the costs of operating the Alliance midstream
system, which was placed into service during the fourth quarter of 2009.
Earnings from BreitBurn Ownership
Quicksilver reported income of $17.0 million attributable to the company's
approximate 31% interest in BreitBurn Energy Partners L.P.'s (NASDAQ: BBEP)
second-quarter 2010 results, including approximately $9.5 million of income
from derivatives. During the third quarter of 2010, Quicksilver received
approximately $6.9 million in cash distributions associated with its
ownership of BreitBurn units.
Development Highlights
In the Fort Worth Basin, the company drilled 22 gross (19.0 net) wells and
connected 28 gross (23.9 net) wells to sales during the third quarter of
2010. The company currently has three rigs working in the basin and
expects to remain at this level through the remainder of the year. The
company also currently has four hydraulic fracturing crews working in the
basin and expects to reduce its inventory of drilled-but-uncompleted wells
in the Fort Worth Basin to approximately 90 by year end.
In the Horseshoe Canyon area of Alberta, Canada, drilling, completion and
pipeline activities resumed in the third quarter as ground conditions
allowed. The company drilled six gross (5.1 net) operated wells during the
third quarter and at this time does not plan to drill any more wells for
the remainder of the year. This will result in a total of 11 gross (9.3
net) wells drilled in the area during 2010. The company expects to
complete or recomplete 13 gross (8.5 net) wells and tie-in 11 gross (8.5
net) wells during the fourth quarter of the year in the Horseshoe Canyon
area.
In October, Quicksilver acquired interests in an additional 47,000 gross
(21,700 net) acres in the Joffre area of the Horseshoe Canyon, where the
company already operates. The $22 million acquisition included
approximately 23 billion cubic feet of proved developed natural gas
reserves and net production of approximately 5 million cubic feet (MMcf)
per day of natural gas.
Horn River Basin
In the Horn River Basin of northeast British Columbia, Quicksilver's C-29-D
well produced at initial rates of approximately 14.4 MMcf per day of
natural gas through a 50/64-inch choke and has averaged more than 12 MMcf
per day during the first 22 days of production. The well tested a
4,600-foot lateral section of the Muskwa formation and included 14 stages
of fracture stimulation. This is the company's third completion in the
basin and the most productive to date. The company's three producible
wells in the Horn River are currently capable of producing more than 15
MMcf per day. The company sells this production through a permanent sales
line that connects to the Spectra pipeline to Fort Nelson. The company
expects to begin completion activities on a fourth well in the basin by
year end. The company has also recently spudded a horizontal well to test
the Exshaw formation, encountered at a vertical depth of approximately
4,350 feet, for commercial oil.
Quicksilver holds 100% working interests in 20 exploratory licenses
covering a total of approximately 130,000 gross contiguous acres in the
Horn River Basin. Drilling activities to date have already validated eight
licenses totaling nearly 50,000 acres. The company expects to validate the
remaining exploratory licenses during the next two winter drilling seasons.
Expanding Acreage Opportunities
Quicksilver has added approximately 145,000 gross (77,000 net) acres to its
existing acreage holdings in the Greater Green River Basin of northern
Colorado and southern Wyoming. The company now has approximately 140,000
net acres in the basin, which it believes to be prospective for both oil
and natural gas in the Niobrara formation. The company anticipates
drilling two exploratory wells on this acreage in 2011.
In the Southern Alberta Bakken Basin of northern Montana, the company also
has rights to approximately 160,000 gross (119,000 net) acres in Glacier
and Toole counties that are primarily held by production from the Cutbank
field. The company believes that this acreage is also prospective for oil
from the Bakken formation.
Capital and Fourth-Quarter 2010 Outlook
During the third quarter of 2010, the company incurred capital costs of
approximately $134 million, of which approximately 85 percent was
associated with drilling and completion activities, approximately nine
percent for midstream activities, approximately five percent for acreage
purchases and approximately one percent for corporate.
Fourth-quarter 2010 production volumes are expected to average in the range
of 385 MMcfe to 395 MMcfe per day. Average unit expenses, on a Mcfe basis,
are expected as follows:
-- Production $ .53 - $ .58
-- Gathering and processing .75 - .80
-- Transportation .40 - .45
-- Production taxes .23 - .25
-- General and administrative .55 - .58
-- Depletion, depreciation & accretion 1.35 - 1.40
The company has derivatives in place to cover approximately 66% of expected
production for the fourth quarter of 2010. A total of 200 MMcf per day of
natural gas is covered by collars with a weighted-average floor price of
$7.40 per thousand cubic feet (Mcf) and 10,000 barrels per day of NGLs are
covered by fixed-price swaps with a weighted-average price of $33.47 per
barrel for the fourth quarter of 2010. In 2011, the company has a total of
150 MMcf per day of natural gas production covered by collars and
fixed-price swaps with a weighted-average floor price of $6.20 per Mcf and
8,000 barrels per day of NGLs are covered by fixed-price swaps with a
weighted-average price of $38.33 per barrel for the year.
Conference Call
The company will host a conference call to discuss third-quarter 2010
operating and financial results and its outlook for the future at 11:00
a.m. eastern time today.
Quicksilver invites interested parties to participate in the call via the
company's website at http://www.qrinc.com or by calling 1-877-313-7932,
using the conference ID number 44054167, prior to 10:55 a.m. eastern time.
A digital replay of the conference call will be available at 3:00 p.m.
eastern time today, and will remain available for 30 days. The replay can
be accessed at 1-800-642-1687 and enter the conference ID number 44054167.
The replay will also be archived for 30 days on the company's website.
Use of Non-GAAP Financial Measure
This news release and the accompanying schedule include the non-generally
accepted accounting principles ('non-GAAP') financial measure of adjusted
net income. The accompanying schedule provides reconciliations of this
non-GAAP financial measure to its most directly comparable financial
measure calculated and presented in accordance with accounting principles
generally accepted in the United States of America ('GAAP'). Our non-GAAP
financial measure should not be considered as an alternative to GAAP
measures such as net income or operating income or any other GAAP measure
of liquidity or financial performance.
About Quicksilver Resources
Fort Worth, Texas-based Quicksilver Resources is a natural gas and crude
oil exploration and production company engaged in the development and
acquisition of long-lived, unconventional natural gas reserves, including
coalbed methane, shale gas, and tight sands gas in North America. The
company has U.S. offices in Fort Worth, Texas; Glen Rose, Texas and Cut
Bank, Montana. Quicksilver's Canadian subsidiary, Quicksilver Resources
Canada Inc., is headquartered in Calgary, Alberta. For more information
about Quicksilver Resources, visit www.qrinc.com.
Forward-Looking Statements
The statements in this news release regarding future events, occurrences,
circumstances, activities, performance, outcomes and results are
forward-looking statements within the meaning of the Private Securities
Litigation Reform Act of 1995. Although these statements reflect the
current views, assumptions and expectations of Quicksilver Resources'
management, the matters addressed herein are subject to numerous risks and
uncertainties, which could cause actual activities, performance, outcomes
and results to differ materially from those indicated. Factors that could
result in such differences or otherwise materially affect Quicksilver
Resources' financial condition, results of operations and cash flows
include: changes in general economic conditions; fluctuations in natural
gas, natural gas liquids and crude oil prices; failure or delays in
achieving expected production from exploration and development projects;
uncertainties inherent in estimates of natural gas, natural gas liquids and
crude oil reserves and predicting natural gas, natural gas liquids and
crude oil reservoir performance; effects of hedging natural gas, natural
gas liquids and crude oil prices; fluctuations in the value of certain of
our assets and liabilities; competitive conditions in our industry; actions
taken or non-performance by third parties, including suppliers,
contractors, operators, processors, transporters, customers and
counterparties; changes in the availability and cost of capital; delays in
obtaining oilfield equipment and increases in drilling and other service
costs; operating hazards, natural disasters, weather-related delays,
casualty losses and other matters beyond our control; the effects of
existing and future laws and governmental regulations, including
environmental and climate change requirements; and the effects of existing
or future litigation; failure to receive a proposal for a transaction to
pursue strategic alternatives for us or that any transaction will be
approved or consummated; costs and expenses associated with our
consideration of potential strategic alternatives, including without
limitation, any related litigation expense; as well as, other factors
disclosed in Quicksilver Resources' filings with the Securities and
Exchange Commission. The forward-looking statements included in this news
release are made only as of the date of this news release, and we undertake
no obligation to update any of these
forward-looking statements to reflect subsequent events or circumstances
except to the extent required by applicable law.
QUICKSILVER RESOURCES INC.
CONDENSED CONSOLIDATED STATEMENTS OF INCOME (LOSS)
In thousands, except for per share data - Unaudited
For the Three Months For the Nine Months
Ended September 30, Ended September 30,
------------------- -------------------
2010 2009 2010 2009
-------- -------- -------- ---------
Revenue
Natural gas, NGL and oil $218,249 $198,287 $631,499 $ 581,156
Sales of purchased natural gas 16,982 5,964 50,027 11,181
Other 2,469 2,406 6,902 6,293
-------- -------- -------- ---------
Total revenue 237,700 206,657 688,428 598,630
-------- -------- -------- ---------
Operating expense
Oil and gas production expense 39,402 29,064 113,593 92,938
Production and ad valorem taxes 9,170 6,630 26,542 18,437
Costs of purchased natural gas 14,638 2,964 51,701 11,546
Other operating costs 1,320 2,066 3,544 5,337
Depletion, depreciation and
accretion 52,542 44,548 149,968 155,210
General and administrative 24,005 17,682 61,745 59,452
-------- -------- -------- ---------
Total expense 141,077 102,954 407,093 342,920
Impairment expense (31,531) - (31,531) (967,126)
-------- -------- -------- ---------
Operating income (loss) 65,092 103,703 249,804 (711,416)
Income (loss) from earnings of
BBEP - net 17,024 (43,685) 24,203 (24,669)
Other income (expense) - net 14,253 (645) 67,646 (739)
Interest expense (51,532) (41,619) (142,171) (149,901)
-------- -------- -------- ---------
Income (loss) before income taxes 44,837 17,754 199,482 (886,725)
Income tax (expense) benefit (18,268) (15,595) (71,569) 301,125
-------- -------- -------- ---------
Net income (loss) 26,569 2,159 127,913 (585,600)
Net income attributable to
noncontrolling interests (4,766) (1,429) (11,119) (4,411)
-------- -------- -------- ---------
Net income (loss) attributable
to Quicksilver $ 21,803 $ 730 $116,794 $(590,011)
======== ======== ======== =========
Income (loss) per common
share - basic $ 0.13 $ - $ 0.69 $ (3.49)
Income (loss) per common
share - diluted $ 0.13 $ - $ 0.68 $ (3.49)
Basic weighted average shares
outstanding 170,307 169,021 170,242 168,917
Diluted weighted average shares
outstanding 171,037 170,657 180,847 168,917
QUICKSILVER RESOURCES INC.
CONDENSED CONSOLIDATED BALANCE SHEETS
In thousands, except share data - Unaudited
September 30, December 31,
2010 2009
----------- -----------
ASSETS
Current assets
Cash and cash equivalents $ 15,078 $ 1,037
Accounts receivable - net of allowance for
doubtful accounts 35,757 63,738
Derivative assets at fair value 142,389 97,957
Other current assets 32,663 54,652
----------- -----------
Total current assets 225,887 217,384
Investment in BBEP 95,124 112,763
Property, plant and equipment
Oil and gas properties, full cost method
(including unevaluated costs of $404,783 and
$458,037, respectively) 2,707,785 2,338,244
Other property and equipment 205,903 204,601
----------- -----------
Property, plant and equipment - net 2,913,688 2,542,845
Assets of midstream operations held for sale 561,924 548,508
Derivative assets at fair value 84,870 14,427
Deferred income taxes 45,179 133,051
Other assets 37,447 43,904
----------- -----------
$ 3,964,119 $ 3,612,882
=========== ===========
LIABILITIES AND EQUITY
Current liabilities
Accounts payable $ 113,509 $ 149,766
Accrued liabilities 109,897 153,598
Derivative liabilities at fair value - 395
Deferred income taxes 51,598 51,675
----------- -----------
Total current liabilities 275,004 355,434
Long-term debt 2,396,705 2,302,123
Liabilities of midstream operations held for sale 267,117 148,191
Asset retirement obligations 52,435 48,472
Other liabilities 28,461 20,691
Deferred income taxes 50,988 41,149
Commitments and contingencies - -
Equity
Preferred stock, par value $0.01, 10,000,000
shares authorized, none outstanding - -
Common stock, $0.01 par value, 400,000,000
shares authorized; 175,543,699 and
174,469,836 shares issued, respectively 1,755 1,745
Paid in capital in excess of par value 753,944 730,265
Treasury stock of 5,046,039 and 4,704,448
shares, respectively (41,428) (36,363)
Accumulated other comprehensive income 179,770 121,336
Retained deficit (64,191) (180,985)
----------- -----------
Quicksilver stockholders' equity 829,850 635,998
Noncontrolling interests 63,559 60,824
----------- -----------
Total equity 893,409 696,822
----------- -----------
$ 3,964,119 $ 3,612,882
=========== ===========
QUICKSILVER RESOURCES INC.
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
In thousands - Unaudited
For the Nine Months
Ended September 30,
----------------------
2010 2009
---------- ----------
Operating activities:
Net income (loss) $ 127,913 $ (585,600)
Adjustments to reconcile net income (loss) to
net cash provided by operating activities:
Impairment expense 31,531 967,126
Depletion, depreciation and accretion 149,968 155,210
Deferred income tax expense (benefit) 71,569 (313,556)
Stock-based compensation 17,343 16,007
Non-cash (gain) loss from commodity derivative
activities (45,801) 2,845
Non-cash interest expense 13,372 40,553
(Income) loss from BBEP in excess of cash
distributions, net of impairment (9,416) 35,770
Gain on sale and disposition of BBEP units (49,850) -
Other (337) 684
Changes in assets and liabilities:
Accounts receivable 25,101 67,555
Derivative assets at fair value 30,816 54,896
Other assets 4,974 4,490
Accounts payable (18,793) (34,543)
Accrued and other liabilities (1,000) 39,156
---------- ----------
Net cash provided by operating activities 347,390 450,593
---------- ----------
Investing activities:
Purchases of property, plant and equipment (494,338) (561,120)
Proceeds from sale of BBEP units 22,498 -
Proceeds from sales of property and equipment 1,030 221,038
---------- ----------
Net cash used for investing activities (470,810) (340,082)
---------- ----------
Financing activities:
Issuance of debt 661,232 1,377,525
Repayments of debt (491,043) (1,507,137)
Debt issuance costs paid (109) (30,995)
Gas Purchase Commitment assumed - 58,294
Gas Purchase Commitment repayments (25,900) (3,804)
Issuance of KGS common units - net of offering
costs 11,054 -
Distributions paid on KGS common units (13,550) (7,344)
Proceeds from exercise of stock options 1,388 822
Taxes paid for equity-based compensation vesting (1,144) (63)
Purchase of treasury stock for stock-based
compensation vesting (4,851) (868)
---------- ----------
Net cash provided by (used for) financing
activities 137,077 (113,570)
---------- ----------
Effect of exchange rate changes on changes in cash (306) 1,779
---------- ----------
Net increase (decrease) in cash and cash
equivalents 13,351 (1,280)
Cash and cash equivalents at beginning of period 1,785 2,848
---------- ----------
Cash and cash equivalents at end of period $ 15,136 $ 1,568
========== ==========
QUICKSILVER RESOURCES INC.
Unaudited Selected Operating Results
Three Months Ended Nine Months Ended
September 30, September 30,
----------------- -----------------
2010 2009 2010 2009
-------- -------- -------- --------
Average Daily Production:
Natural Gas (Mcfd) 281,997 221,168 267,237 232,728
NGL (Bbld) 12,562 14,024 11,895 14,074
Oil (Bbld) 834 981 851 1,236
Total (Mcfed) 362,377 311,196 343,717 324,590
Average Realized Prices:
Natural Gas (per Mcf) $ 6.83 $ 7.69 $ 7.05 $ 7.41
NGL (per Bbl) $ 30.91 $ 28.15 $ 31.12 $ 24.57
Oil (per Bbl) $ 69.32 $ 60.55 $ 70.31 $ 47.44
Total (Mcfe) $ 6.55 $ 6.93 $ 6.73 $ 6.56
Expense per Mcfe:
Oil and gas production expense:
Lease operating expense $ 1.16 $ 0.99 $ 1.19 $ 1.02
Equity compensation 0.02 0.03 0.02 0.03
-------- -------- -------- --------
Total oil and gas production expense: $ 1.18 $ 1.02 $ 1.21 $ 1.05
Production and ad valorem taxes $ 0.28 $ 0.23 $ 0.28 $ 0.21
Depletion, depreciation and accretion $ 1.58 $ 1.56 $ 1.60 $ 1.75
General and administrative expense:
Litigation settlement $ 0.07 $ 0.03 $ 0.03 $ 0.07
Cash expense 0.50 0.46 0.47 0.45
Equity compensation 0.15 0.13 0.16 0.15
-------- -------- -------- --------
Total general and administrative
expense $ 0.72 $ 0.62 $ 0.66 $ 0.67
QUICKSILVER RESOURCES INC.
Production, on a million cubic feet of natural gas equivalent (MMcfe) per
day basis, by operating area
Three Months Ended Nine Months Ended
September 30, September 30,
------------------- -------------------
2010 2009 2010 2009
--------- --------- --------- ---------
Texas 295.1 240.2 272.7 255.3
Other U.S. 3.7 3.2 4.2 3.2
--------- --------- --------- ---------
Total U.S. 298.8 243.4 276.9 258.5
Canada 63.6 67.8 66.8 66.1
--------- --------- --------- ---------
Total Company 362.4 311.2 343.7 324.6
========= ========= ========= =========
QUICKSILVER RESOURCES INC.
RECONCILIATION OF NET INCOME (LOSS) TO ADJUSTED NET INCOME
In thousands, except per share data - Unaudited
For the Three Months For the Nine Months
Ended September 30, Ended September 30,
---------------------- ----------------------
2010 2009 2010 2009
---------- ---------- ---------- ----------
Net income (loss) $ 21,803 $ 730 $ 116,794 $ (590,011)
---------- ---------- ---------- ----------
Adjustments
Impairment expense 31,531 - 31,531 967,126
Impairment of investment
in BBEP - - - 102,084
Equity portion of BBEP
impairment expense - - - 35,044
Crestwood Transaction
expenses 2,560 - 2,560 -
Equity portion of early
settlement of hedges
from BBEP - (10,094) - (28,602)
Equity portion of
interest rate
derivatives from BBEP (548) (136) (1,535) 6,841
Equity portion of
commodity derivatives
from BBEP (9,005) 60,160 (2,879) (78,663)
Equity portion of loss
from sale of properties
from BBEP 133 - 379 -
BBEP settlement - - (18,000) -
Gain on sale and
disposition of BBEP units (14,424) - (49,850) -
Unrealized valuation on
Gas Purchase Commitment (5,496) - (5,960) -
Debt termination-related
expenses - - - 27,122
Legal settlement 2,400 - 2,400 5,000
---------- ---------- ---------- ----------
Total adjustments before
income tax expense 7,151 49,930 (41,354) 1,035,952
Income tax expense for
above adjustments (2,503) (17,475) 14,474 (344,896)
---------- ---------- ---------- ----------
Total adjustments after
income tax expense 4,648 32,455 (26,880) 691,056
Current quarter effect of
tax rate changes to
prior quarters 2,226 9,553 - -
---------- ---------- ---------- ----------
Total adjustments after tax 6,874 42,008 (26,880) 691,056
Adjusted net income $ 28,677 $ 42,738 $ 89,914 $ 101,045
========== ========== ========== ==========
Adjusted net income per
common share - Diluted $ 0.17 $ 0.25 $ 0.53 $ 0.58
Diluted weighed average
common shares outstanding 180,853 180,474 180,847 179,972
KWK 10-18
Media Contact:
Tom Johnson
Chuck Dohrenwend
The Abernathy MacGregor Group
(212) 371-5999
Investor Contact:
Rick Buterbaugh
(817) 665-4835
