W&T Offshore Reports Fourth Quarter and Full Year 2009 Financial and Operational Results
HOUSTON, Feb. 25 /PRNewswire-FirstCall/ -- W&T Offshore, Inc. (NYSE: WTI) today announces financial and operational results for the fourth quarter and full year 2009. Some of the highlights include:
-- Fourth quarter of 2009 net income and earnings per share were $64.0
million and $0.84 per share, respectively, versus a net loss of $851.4
million and loss per share of $11.21 during the fourth quarter of 2008.
-- Production for 2009 was 94.8 Bcfe, sold at an average realized price of
$6.39 per Mcfe.
-- Long-term debt and asset retirement obligations decreased $200.2 million
and $199.1 million, respectively.
-- Capital budget for 2010 of $450 million, an increase of 63% over 2009
expenditures.
-- 77% success in 2009 exploration and development drilling program,
including successfully drilling eight of ten exploration wells and two
of three development wells.
-- LOE decreased $25.8 million for the year through divestitures of
non-core assets and cost reduction initiatives.
Tracy W. Krohn, Chairman and Chief Executive Officer, commented, "In 2009, we focused on analyzing the best investment opportunities, be it drilling, joint ventures or acquisitions, while implementing a profitability initiative and divesting certain non-core assets to improve our margins. As a result, we have identified over 160 prospects that we are tracking in our prospect inventory database, and we significantly reduced both operating costs and long-term asset retirement obligations. We are better able to take advantage of rising energy prices with a lower cost structure. We enter 2010 as a leaner, more efficient company with internally identified opportunities, the ability to capitalize on acquisitions and/or joint ventures and a Capital Budget of $450 million, which represents a 63% increase over our capital expenditures in 2009."
Revenues, Net Income and EPS: Net income for the fourth quarter of 2009 was $64.0 million, or $0.84 per common share, on revenues of $176.1 million, compared to a net loss for the same quarter of 2008 of $851.4 million, or $11.21 per common share, on revenues of $108.3 million. Net income increased in the fourth quarter of 2009, principally due to the $1.2 billion ceiling test impairment in 2008, $38.4 million in additional tax benefits related to new tax legislation in 2009, higher production volumes in 2009 and an increase in our average realized unhedged price to $7.67 per thousand cubic feet equivalent ("Mcfe") in 2009 from $6.68 per Mcfe in 2008. Production was higher during the fourth quarter of 2009 compared to the corresponding period in 2008 due to the deferral of production caused by Hurricane Gustav in late August 2008 and Hurricane Ike in early September 2008. The Worker, Homeownership and Business Assistance Act of 2009, which extended the net operating loss carryback period from two years to five years, resulted in additional tax benefits to us.
Net income for the fourth quarter of 2009 excluding special items would have been approximately $27.1 million, or $0.36 per common share. The net loss excluding special items for the corresponding quarter of 2008 was approximately $84.3 million, or $1.11 per common share. See the "Reconciliation of Net Income (Loss) to Net Income (Loss) Excluding Special Items" table at the back of this press release for a description of the special items.
The net loss for the year ended December 31, 2009 was $187.9 million, or $2.51 per common share, on revenues of $611.0 million, compared to a net loss of $558.8 million, or $7.36 per common share, on revenues of $1.2 billion for 2008. Excluding special items, the net loss for 2009 would have been $81.5 million, or $1.09 per common share, compared to net income excluding special items of $200.9 million, or $2.63 per common share, in the 2008 period. The net loss, before special items, for the year 2009 compared to net income, before special items, in 2008 resulted from lower average commodity prices throughout a majority of 2009 and lower production volumes. This decrease was partially offset by lower lease operating expenses ("LOE"), gathering and transportation costs, production taxes, depreciation, depletion, amortization and accretion ("DD&A") and general and administrative expenses ("G&A").
Cash Flow from Operating activities and Adjusted EBITDA: EBITDA and Adjusted EBITDA are non-GAAP measures and are defined in "Non-GAAP Information" later in this press release. Adjusted EBITDA for the fourth quarter of 2009 was $113.9 million, compared to $22.2 million during the prior year's fourth quarter. Net cash provided by (used in) operating activities for the fourth quarter of 2009 increased to $64.4 million from ($157.8) million in 2008, respectively. Adjusted EBITDA and cash flow from operating activities for the fourth quarter of 2009 were significantly higher than for the corresponding period in the previous year due to the deferral of production caused by Hurricane Gustav in late August 2008 and Hurricane Ike in early September 2008.
For the year ended December 31, 2009, adjusted EBITDA was $342.2 million, compared to $883.9 million for the year 2008. Net cash provided by operating activities for the full year of 2009 decreased to $156.3 million from $882.5 million in 2008. Cash flow from operating activities and adjusted EBITDA were lower for the year ended December 31, 2009 compared to the prior year due to lower realized prices on sales of our oil and natural gas production, lower production volumes and a significant increase in working capital requirements, primarily to fund accounts payable, plugging and abandonment work and accounts receivable balances.
Production and Prices: During the fourth quarter of 2009, we sold, on a natural gas equivalent ("Bcfe") basis, 22.9 Bcfe at an average price of $7.67 per Mcfe, compared to 16.2 Bcfe sold at an average price of $6.68 per Mcfe in the comparable 2008 period. Higher production volumes during the fourth quarter of 2009 versus 2008 were largely due to deferred production from Hurricanes Gustav and Ike during 2008.
For the year ended December 31, 2009, we sold, on a natural gas equivalent basis, 94.8 Bcfe at an average price of $6.39 per Mcfe, compared to 97.9 Bcfe sold at an average price of $12.42 per Mcfe for the 2008 period. The decline in production is largely attributable to divestitures completed in 2009 as well as natural reservoir declines, partially offset by deferred production from Hurricane Gustav and Ike that came back online during 2009.
Lease Operating Expenses: LOE for the fourth quarter of 2009 decreased to $45.8 million from $73.2 million in the fourth quarter of 2008. This LOE decline was due to lower base lease operating expenditures as a result of the divestitures, our cost reduction efforts and lower hurricane remediation expenditures.
LOE for the year ended December 31, 2009 was $203.9 million, or $2.15 per Mcfe, compared to $229.7 million, or $2.35 per Mcfe, in 2008. LOE on a nominal basis decreased due to our cost reduction efforts, the sale of certain non-core assets and decreased expenditures on our facilities for maintenance, partially offset by higher insurance costs and increased workover activity. Included in lease operating expenses for 2009 and 2008 are $18.4 million and $17.7 million, respectively, of hurricane remediation costs related to Hurricanes Ike and Gustav that were either not yet approved by our insurance underwriters' adjuster or were not covered by insurance.
Depreciation, depletion, amortization and accretion: DD&A decreased to $78.3 million, or $3.42 per Mcfe, in the fourth quarter of 2009 from $108.6 million, or $6.69 per Mcfe, in the same period of 2008. DD&A for the year ended 2009 was $342.5 million, or $3.61 per Mcfe, compared to DD&A of $521.8 million, or $5.33 per Mcfe, for the same period in 2008. The decrease is primarily attributable to a lower depreciable base (resulting from ceiling test impairments of $1.2 billion and $218.9 million recognized in the fourth quarter of 2008 and the first quarter of 2009, respectively, and a net reduction of our asset retirement obligations of $199.1 million from the sale of certain non-core assets, revisions to our estimates and other items), partially offset by lower oil and natural gas reserves.
Capital Expenditures and Operations Update: For the year ended December 31, 2009, our capital expenditures were $276.1 million, consisting of $90.6 million for exploration activities, $162.1 million for development activities and $23.4 million for acquisitions, seismic, capitalized interest and other leasehold costs. Our capital expenditures were funded by operating cash flow and cash on hand. Capital expenditures and acquisitions in 2008 were $774.9 million.
In 2009, the Company made discoveries and successfully completed drilling on eight of 10 exploration wells, for a success rate of 80%, which included seven out of nine conventional shelf wells, and one well in the marshlands of southern Louisiana. Additionally, the Company successfully drilled and completed two of three development wells, both of which were on the conventional shelf. For the 13 wells drilled in 2009, the Company achieved a success rate of 77%.
Drilling Highlights: In the fourth quarter of 2009, the Company was 100% successful in the drilling of two exploration wells. One of the wells was located onshore in South Louisiana while the other was on the conventional shelf.
Commercial Wells:
-----------------
Well Category Working Interest %
---- -------- ------------------
S. Louisiana Well Exploration / Onshore 50%
S. Timbalier 23 SD-18 ST2 Exploration / Conv. Shelf 30%
After the close of the first quarter, the Company drilled one non-commercial well:
Non-commercial Wells:
---------------------
Well Category Working Interest %
---- -------- ------------------
Viosca Knoll 734 A-4 Exploration / Conv. Shelf 100%
Reserves: As of December 31, 2009, total proved reserves were 371.0 Bcfe, compared to proved reserves of 491.1 Bcfe as of December 31, 2008. This decline in reserves was primarily due to production, the divestiture of certain non-core assets, the use of average prices versus end of year prices, and downward revisions because of the de-booking of proved undeveloped reserves ("PUDs") as a result of the SEC's new five-year limitation on the life of PUDs from the date they were initially recorded. Partially offsetting this decline were discoveries and extensions from our drilling, recomplete and workover programs. Year-end 2009 proved reserves are comprised of 45% natural gas and 55% oil and natural gas liquids. In accordance with guidelines established by the SEC, our proved reserves as of December 31, 2009 were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average price for each product, calculated as the unweighted arithmetic average of the first-day-of-the-month price for the period January 2009 through December 2009. The present value of our total proved reserves discounted at 10% (referred to as "PV-10"*), which includes the impact of estimated asset retirement obligations, is $890 million. This is based on average prices of $3.87 per Mcf for natural gas and $57.65 per Bbl for oil and natural gas liquids, adjusted by lease for quality, transportation fees and regional price differentials. The estimate of proved reserves is based on a reserve report prepared by Netherland, Sewell & Associates, Inc., the Company's independent petroleum consultant.
* The PV-10 value is a non-GAAP measure and defined in the "Non-GAAP Information" later in this press release.
The Company's proved reserves are summarized in the table below.
As of December 31, 2009
---------------------------------------
% of
Oil Gas Total Total
Classification of Reserves (MMBbls) (Bcf) (Bcfe) Proved
-------------------------- -------- ------ ------ ------
Proved developed producing 12.7 86.6 162.5 44%
Proved developed non-
producing (1) 11.0 54.7 121.0 32%
---- ---- ----- ---
Total proved developed 23.7 141.3 283.5 76%
Proved undeveloped 10.5 24.5 87.5 24%
---- ---- ---- ---
Total proved 34.2 165.8 371.0 100%
==== ===== ===== ===
(1) Includes approximately 1.7 Bcfe of reserves with a PV-10 (before
estimated asset retirement obligations) of $12.4 million that were
shut-in at December 31, 2009 because of damage caused by Hurricane Ike
in September 2008. We anticipate that the majority of these reserves
will be reclassified to producing in the first half of 2010.
2009 Reserve Reconciliation:
Total Oil
and
Oil and Natural Natural
Liquids Gas Gas
(MBbls) (MMcf) (MMcfe)
------- ------- -------
Proved reserves as of December 31, 2008 43,876 227,872 491,125
Revisions due to pricing 1,477 (6,371) 2,489
Revisions due to performance (154) (3,840) (4,758)
Revisions due to SEC 5-year rule for PUDs (3,397) (2,831) (23,215)
Discoveries and extensions 1,481 14,511 23,402
Purchases of minerals in place 43 434 692
Sales of minerals in place (1,927) (12,397) (23,957)
Production (7,197) (51,621) (94,806)
------ ------- -------
Proved reserves as of December 31, 2009 34,202 165,757 370,972
====== ======= =======
2010 Capital Expenditures Budget: Our total capital expenditure budget for 2010 is $450 million and is expected to be funded with internally generated cash flow and cash on hand. The budget included seven conventional shelf exploration wells. It also included other capital items such as well recompletions, facilities capital, seismic and leasehold items. We have recently added three wells to the plan and continue to evaluate the expected costs associated with the original seven wells. Our plan now includes ten wells plus the other capital items budgeted at $153 million. The balance of the $450 million budget will be allocated to acquisitions, additional drilling opportunities from the Company's prospect inventory, joint venture projects and/or other drilling ventures. WTI is determined to remain as flexible as possible and believes this strategy holds the best promise for value creation and growth.
Outlook: The guidance for first quarter and full year 2010 represents the Company's best estimate of likely future results, and is affected by the factors described below in "Forward-Looking Statements."
Guidance for the first quarter and full year 2010 are shown in the table below. Production guidance includes the planned build up from our original seven wells and does not reflect any build up from the remainder of our capital budget.
2010 Production and Cost Guidance:
Estimated Production First Quarter Full-Year
2010 2010
Crude oil and NGL (MMBbls) 1.5 – 1.6 4.6 – 6.2
Natural gas (Bcf) 8.9 – 9.9 32.4 – 42.8
Total (Bcfe) 17.8 – 19.7 60.0 – 80.0
Operating Expenses ($ in
millions, except as noted) First Quarter Full-Year
2010 2010
Lease operating expenses $45 – $56 $168 – $206
Gathering, transportation &
production taxes $3 – $4 $14 – $18
General and administrative $11 – $13 $43 – $47
Income tax rate* 35% 35%
* Exclusive of valuation allowance adjustments.
Conference Call Information: W&T will hold a conference call to discuss financial and operational results on Thursday, February 25, 2010 at 10:00 a.m. Eastern Time / 9:00 a.m. Central Time. To participate, dial (480) 629-9819 a few minutes before the call begins. The call will also be broadcast live over the Internet from the Company's website at www.wtoffshore.com. A replay of the conference call will be available approximately two hours after the end of the call until Thursday, March 4, 2010, and may be accessed by calling (303) 590-3030 and using the pass code 4206518.
About W&T Offshore
W&T Offshore is an independent oil and natural gas company focused primarily in the Gulf of Mexico, including exploration in the deepwater and deep shelf regions, where it has developed significant technical expertise. W&T has grown through acquisition, exploitation and exploration and holds working interests in approximately 82 fields, in federal and state waters and a majority of its daily production is derived from wells it operates. For more information on W&T Offshore, please visit its Web site at www.wtoffshore.com.
Forward-Looking Statements
This press 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. These forward-looking statements reflect our current views with respect to future events, based on what we believe are reasonable assumptions. No assurance can be given, however, that these events will occur. These statements are subject to risks and uncertainties that could cause actual results to differ materially including, among other things, market conditions, oil and gas price volatility, uncertainties inherent in oil and gas production operations and estimating reserves, unexpected future capital expenditures, competition, the success of our risk management activities, governmental regulations, uncertainties and other factors discussed in our Annual Report on 10-K for the year ended December 31, 2008 (www.sec.gov).
Contacts: Janet Yang, Finance Manager investorrelations@wtoffshore.com 713-297-8024 Ken Dennard / ksdennard@drg-e.com Lisa Elliott / lelliott@drg-e.com DRG&E / 713-529-6600
W&T OFFSHORE, INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Income (Loss)
(Unaudited)
Three Months Ended Twelve Months Ended
December 31, December 31,
---------------- ----------------
2009 2008 2009 2008
---- ---- ---- ----
(In thousands, except per share data)
Revenues $176,100 $108,306 $610,996 $1,215,609
-------- -------- -------- ----------
Operating costs and expenses:
Lease operating expenses (1) 45,792 73,193 203,922 229,747
Gathering, transportation
costs and production taxes 3,299 1,831 15,163 24,784
Depreciation, depletion
and amortization 72,634 98,386 308,076 482,464
Asset retirement
obligation accretion 5,700 10,195 34,461 39,312
Impairment of oil and
natural gas properties (2) - 1,182,758 218,871 1,182,758
General and administrative
expenses 11,065 12,931 42,990 47,225
Derivative loss (gain) 2,675 (4,433) 7,372 16,464
----- ------ ----- ------
Total costs and expenses 141,165 1,374,861 830,855 2,022,754
------- --------- ------- ---------
Operating income (loss) 34,935 (1,266,555) (219,859) (807,145)
Interest expense:
Incurred 11,404 13,791 46,749 54,001
Capitalized (1,284) (4,252) (6,662) (19,292)
Loss on extinguishment of debt - - 2,926 -
Other income 80 4,101 842 13,372
--- ----- --- ------
Income (loss) before
income tax benefit 24,895 (1,271,993) (262,030) (828,482)
Income tax benefit (39,059) (420,577) (74,111) (269,663)
------- -------- ------- --------
Net income (loss) $63,954 $(851,416) $(187,919) $(558,819)
======= ========= ========= =========
Basic and diluted earnings
(loss) per common share $0.84 $(11.21) $(2.51) $(7.36)
Weighted average common
shares outstanding 74,148 75,940 74,852 75,917
Consolidated Cash Flow
Information
Net cash provided by (used
in) operating activities $64,395 $(157,763) $156,266 $882,496
Capital expenditures-oil
and natural gas properties 169 153,255 276,134 774,879
Other Financial Information
EBITDA $113,269 $24,784 $338,623 $897,389
Adjusted EBITDA 113,868 22,216 342,242 883,888
(1) Included in lease operating expenses for the years ended December 31,
2009 and 2008 are hurricane remediation costs of $18.4 million and
$17.7 million, respectively, related to Hurricanes Ike and Gustav that
were either not yet approved by our insurance underwriters' adjuster
or were not covered by insurance.
(2) The carrying amount of our oil and natural gas properties has been
written down by $218.9 million as of March 31, 2009 through
application of the full cost ceiling limitation as prescribed by the
SEC, primarily as a result of lower natural gas prices at March 31,
2009, as compared to December 31, 2008. This amount includes an
increase of $13.9 million from the previously reported amount of
$205.0 million as a result of further analysis of our March 31, 2009
ceiling test impairment calculation. As such, operating income, net
income and our basic and diluted loss per common share for the first
quarter of 2009 have been adjusted as well. In December 2008, the
carrying amount of our oil and natural gas properties was written down
by $1.2 billion ($768.8 million after-tax) through application of the
full cost ceiling limitation as prescribed by the SEC, primarily as a
result of the significant decline in both oil and natural gas prices
as of December 31, 2008.
W&T OFFSHORE, INC. AND SUBSIDIARIES
Condensed Operating Data
(Unaudited)
Three Months Twelve Months
Ended Ended
December 31, December 31,
------------ ------------
2009 2008 2009 2008
----- ----- ----- -----
Net sales:
Natural gas (MMcf) 11,696 10,485 51,621 56,072
Oil (MBbls) 1,871 958 7,197 6,970
Total natural gas and oil (MBoe) (1) 3,820 2,705 15,801 16,315
Total natural gas and oil (MMcfe) (2) 22,922 16,233 94,806 97,892
Average daily equivalent sales (MBoe/d) 41.5 29.4 43.3 44.6
Average daily equivalent sales (MMcfe/d) 249.2 176.4 259.7 267.5
Average realized sales prices (Unhedged):
Natural gas ($/Mcf) $3.92 $5.90 $3.97 $9.40
Oil ($/Bbl) 69.47 48.59 55.67 98.72
Barrel of oil equivalent ($/Boe) 46.02 40.06 38.32 74.50
Natural gas equivalent ($/Mcfe) 7.67 6.68 6.39 12.42
Average realized sales prices (Hedged): (3)
Natural gas ($/Mcf) $3.90 $5.98 $3.96 $9.42
Oil ($/Bbl) 69.47 50.24 55.67 94.67
Barrel of oil equivalent ($/Boe) 45.96 40.95 38.30 72.82
Natural gas equivalent ($/Mcfe) 7.66 6.83 6.38 12.14
Average per Boe ($/Boe):
Lease operating expenses $11.99 $27.05 $12.91 $14.08
Gathering and transportation costs and
production taxes 0.86 0.68 0.96 1.52
Depreciation, depletion, amortization
and accretion 20.50 40.13 21.68 31.98
General and administrative expenses 2.90 4.78 2.72 2.89
Net cash provided by (used in) operating
activities 16.86 (58.31) 9.89 54.09
Adjusted EBITDA 29.81 8.21 21.66 54.18
Average per Mcfe ($/Mcfe):
Lease operating expenses $2.00 $4.51 $2.15 $2.35
Gathering and transportation costs and
production taxes 0.14 0.11 0.16 0.25
Depreciation, depletion, amortization
and accretion 3.42 6.69 3.61 5.33
General and administrative expenses 0.48 0.80 0.45 0.48
Net cash provided by (used in) operating
activities 2.81 (9.72) 1.65 9.01
Adjusted EBITDA 4.97 1.37 3.61 9.03
(1) One million barrels of oil equivalent (MMBoe), one thousand barrels of
oil equivalent (Mboe) and one barrel of oil equivalent (Boe) are
determined using the ratio of one Bbl of crude oil, condensate or
natural gas liquids to six Mcf of natural gas (totals may not add due
to rounding).
(2) One billion cubic feet equivalent (Bcfe), one million cubic feet
equivalent (MMcfe) and one thousand cubic feet equivalent (Mcfe) are
determined using the ratio of six Mcf of natural gas to one Bbl of
crude oil, condensate or natural gas liquids (totals may not add due
to rounding).
(3) Data for 2008 and 2009 includes the effects of our commodity
derivative contracts that did not qualify for hedge accounting.
W&T OFFSHORE, INC. AND SUBSIDIARIES
Condensed Consolidated Balance Sheets
(Unaudited)
December 31, December 31,
------------ ------------
2009 2008
---- ----
(In thousands, except share data)
Assets
Current assets:
Cash and cash equivalents $38,187 $357,552
Receivables:
Oil and natural gas sales 54,978 36,550
Joint interest and other 51,312 83,178
Insurance 30,543 2,040
Income taxes 85,457 34,077
------ ------
Total receivables 222,290 155,845
Prepaid expenses and other assets 28,777 30,417
------ ------
Total current assets 289,254 543,814
Property and equipment – at cost:
Oil and natural gas properties and
equipment (full cost method, of which
$77,301 at December 31, 2009 and $99,139
at December 31, 2008 were excluded from
amortization) 4,732,696 4,684,730
Furniture, fixtures and other 15,080 14,370
------ ------
Total property and equipment 4,747,776 4,699,100
Less accumulated depreciation, depletion
and amortization 3,752,980 3,217,759
--------- ---------
Net property and equipment 994,796 1,481,341
Restricted deposits for asset retirement
obligations 30,614 24,138
Deferred income taxes 5,117 -
Other assets 7,052 6,893
----- -----
Total assets $1,326,833 $2,056,186
========== ==========
Liabilities and Shareholders’ Equity
Current liabilities:
Current maturities of long-term debt $- $3,000
Accounts payable 115,683 228,899
Undistributed oil and natural gas proceeds 32,216 29,716
Asset retirement obligations 117,421 67,007
Accrued liabilities 13,509 18,254
Deferred income taxes 5,117 -
----- ---
Total current liabilities 283,946 346,876
Long-term debt, less current maturities –
net of discount 450,000 650,172
Asset retirement obligations, less current
portion 231,379 480,890
Other liabilities 2,558 6,021
Commitments and contingencies
Shareholders’ equity:
Common stock, $0.00001 par value;
118,330,000 shares authorized; 77,579,968
issued and 74,710,795 outstanding at
December 31, 2009; 76,291,408 issued
and outstanding at December 31, 2008 1 1
Additional paid-in capital 373,050 372,595
Retained earnings 10,066 200,274
Treasury stock, at cost (24,167) -
Accumulated other comprehensive loss - (643)
--- ----
Total shareholders’ equity 358,950 572,227
------- -------
Total liabilities and shareholders’
equity $1,326,833 $2,056,186
========== ==========
W&T OFFSHORE, INC. AND SUBSIDIARIES
Condensed Consolidated Statements of Cash Flows
(Unaudited)
Twelve Months Ended
December 31,
---------------
2009 2008
---- ----
(In thousands)
Operating activities:
Net loss $(187,919) $(558,819)
Adjustments to reconcile net loss to net cash
provided by operating activities:
Depreciation, depletion, amortization and
accretion 345,637 521,776
Impairment of oil and natural gas properties 218,871 1,182,758
Amortization of debt issuance costs and
discount on indebtedness 1,838 2,749
Loss on extinguishment of debt 2,817 -
Share-based compensation related to
restricted stock issuances 6,380 6,029
Unrealized derivative loss (gain) 693 (13,501)
Deferred income taxes (346) (249,445)
Changes in operating assets and liabilities (232,703) (9,884)
Other 998 833
--- ---
Net cash provided by operating activities 156,266 882,496
------- -------
Investing activities:
Acquisition of property interest (2,421) (116,551)
Investment in oil and natural gas properties
and equipment (273,713) (658,328)
Proceeds from sales of oil and natural gas
properties and equipment 32,226 -
Proceeds from insurance 6,916 5,828
Purchases of furniture, fixtures and other (705) (4,812)
---- ------
Net cash used in investing activities (237,697) (773,863)
-------- --------
Financing activities:
Borrowings of long-term debt 205,441 -
Repayments of long-term debt (410,941) (3,000)
Dividends to shareholders (9,158) (59,999)
Repurchases of common stock (24,167) -
Other 891 (2,132)
--- ------
Net cash used in financing activities (237,934) (65,131)
-------- -------
Increase (decrease) in cash and cash
equivalents (319,365) 43,502
Cash and cash equivalents, beginning of period 357,552 314,050
------- -------
Cash and cash equivalents, end of period $38,187 $357,552
======= ========
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Certain financial information included in our financial results are not
measures of financial performance recognized by accounting principles
generally accepted in the United States, or GAAP. These non-GAAP
financial measures are "Adjusted Net Income," "EBITDA," "Adjusted EBITDA,"
and "PV-10." Our management uses these non-GAAP measures in its analysis
of our performance. These disclosures may not be viewed as a substitute
for results determined in accordance with GAAP and are not necessarily
comparable to non-GAAP performance measures, which may be reported by
other companies.
Reconciliation of Net Income (Loss) to Net Income (Loss)
Excluding Special Items
"Net Income (Loss) Excluding Special Items" does not include the
unrealized derivative (gain) loss, the loss on extinguishment of debt, the
impairment of oil and gas properties and associated tax effects and tax
impact of the new tax legislation. Net Income (Loss) excluding special
items is presented because the timing and amount of these items cannot be
reasonably estimated and affect the comparability of operating results
from period to period, and current periods to prior periods.
Three Months Ended Twelve Months Ended
December 31, December 31,
--------------- ---------------
2009 2008 2009 2008
---- ---- ---- ----
(In thousands, except per share amounts)
(Unaudited)
Net income (loss) $63,954 $(851,416) $(187,919) $(558,819)
Unrealized derivative loss
(gain) 599 (2,568) 693 (13,501)
Loss on extinguishment of debt - - 2,926 -
Income tax adjustment for
above items 940 849 (1,024) 4,394
Impairment of oil and natural
gas properties - 1,182,758 218,871 1,182,758
Income tax adjustment on
impairment - (413,965) (76,605) (413,965)
Income tax impact of new
legislation (1) (38,407) - (38,407) -
------- --- ------- ---
Net income (loss) excluding
special items $27,086 $(84,342) $(81,465) $200,867
======= ======== ======== ========
Basic and diluted earnings
(loss) per common share,
excluding special items $0.36 $(1.11) $(1.09) $2.63
===== ====== ====== =====
(1) The Worker, Homeownership and Business Assistance Act of 2009.
Reconciliation of Net Income to Adjusted EBITDA
We define EBITDA as net income (loss) plus income tax expense (benefit),
net interest expense, depreciation, depletion, amortization, accretion and
impairment of oil and gas properties. We believe the presentation of
EBITDA and Adjusted EBITDA provide useful information regarding our
ability to service debt and to fund capital expenditures and help our
investors understand our operating performance and make it easier to
compare our results with those of other companies that have different
financing, capital and tax structures. Adjusted EBITDA excludes the loss
on extinguishment of debt and the unrealized gain or loss related to our
open derivative contracts. Although not prescribed under generally
accepted accounting principles, we believe the presentation of EBITDA and
Adjusted EBITDA are relevant and useful because they help our investors
understand our operating performance and make it easier to compare our
results with those of other companies that have different financing,
capital and tax structures. EBITDA and Adjusted EBITDA should not be
considered in isolation from or as a substitute for net income, as an
indication of operating performance or cash flows from operating
activities or as a measure of liquidity. EBITDA and Adjusted EBITDA, as
we calculate them, may not be comparable to EBITDA and Adjusted EBITDA
measures reported by other companies. In addition, EBITDA and Adjusted
EBITDA do not represent funds available for discretionary use. The
following table presents a reconciliation of our consolidated net income
(loss) to consolidated EBITDA and Adjusted EBITDA
Three Months Ended Twelve Months Ended
December 31, December 31,
--------------- ---------------
2009 2008 2009 2008
---- ---- ---- ----
(In thousands)
(Unaudited)
Net income (loss) $63,954 $(851,416) $(187,919) $(558,819)
Income tax benefit (39,059) (420,577) (74,111) (269,663)
Net interest expense 10,040 5,438 39,245 21,337
Depreciation, depletion,
amortization and accretion 78,334 108,581 342,537 521,776
Impairment of oil and natural
gas properties - 1,182,758 218,871 1,182,758
--- --------- ------- ---------
EBITDA 113,269 24,784 338,623 897,389
Adjustments:
Loss on extinguishment of debt - - 2,926 -
Unrealized derivative loss (gain) 599 (2,568) 693 (13,501)
--- ------ --- -------
Adjusted EBITDA $113,868 $22,216 $342,242 $883,888
======== ======= ======== ========
Price Sensitivities
In addition to the SEC Case proved reserves, our independent petroleum
consultant also prepared estimates of our year-end proved reserves using
two alternative commodity price assumptions. The following table
summarizes our total proved reserves as of December 31, 2009 under each of
the three cases:
Total Proved Reserves
As of December 31, 2009
-----------------------
Oil Gas Total PV-10 (3)
Case (MMBbls) (Bcf) (Bcfe) (In millions)
---- -------- ----- ----- -------------
SEC 34.2 165.8 371.0 $890.0
Flat (1) 35.8 181.1 396.0 1,578.5
NYMEX (2) 36.7 186.0 406.0 1,841.1
(1) The Flat Case was based on the posted spot prices as of December 31,
2009 for both oil and natural gas. For oil and natural gas liquids,
the West Texas Intermediate posted price of $76.00 per barrel was
adjusted by lease for quality, transportation fees and regional price
differentials. For natural gas, the Henry Hub spot price of $5.79 per
MMBTU was adjusted by lease for energy content, transportation fees
and regional price differentials. Such prices were held constant
throughout the estimated lives of the reserves. Future production and
development costs are based on current costs with no escalations.
(2) The NYMEX Case was based on the forward closing prices on the New York
Mercantile Exchange for oil and natural gas as of December 31, 2009.
For oil and natural gas liquids, the price was based on a crude oil
price which increased from $79.36 per Bbl to $101.92 per Bbl during
the life of the reserves and was adjusted by lease for quality,
transportation fees and regional price differentials. For natural
gas, the price was based on a natural gas price which increased from
$5.57 per MMBTU to $9.05 per MMBTU over the life of the properties and
was adjusted by lease for energy content, transportation fees and
regional price differentials. Future production and development costs
are based on current costs with no escalations.
(3) We refer to PV-10 as the present value of estimated future net
revenues before asset retirement obligations, as calculated by our
independent petroleum consultant, adjusted by the Company to include
estimated asset retirement obligations discounted using a 10% annual
discount rate. PV-10 is not a financial measure prescribed under
generally accepted accounting principles ("GAAP"). Management
believes that the presentation of the non-GAAP financial measure of
PV-10 provides useful information to investors because it is widely
used by professional analysts and sophisticated investors in
evaluating oil and natural gas companies. Management believes that
PV-10 is relevant and useful for evaluating the relative monetary
significance of oil and natural gas properties. Further, professional
analysts and sophisticated investors may utilize the measure as a
basis for comparison of the relative size and value of our reserves to
other companies' reserves. Management also uses this pre-tax measure
when assessing the potential return on investment related to oil and
natural gas properties and in evaluating acquisition opportunities.
Because there are many unique factors that can impact an individual
company when estimating the amount of future income taxes to be paid,
we believe the use of a pre-tax measure is valuable for evaluating us.
PV-10 is not a measure of financial or operating performance under
GAAP, nor is it intended to represent the current market value of our
estimated oil and natural gas reserves. PV-10 should not be
considered in isolation or as a substitute for the standardized
measure of discounted future net cash flows as defined under GAAP.
SOURCE W&T Offshore, Inc.
Released February 25, 2010