Provides Guidance for the Fourth Quarter
HOUSTON, Nov. 9 /PRNewswire-FirstCall/ -- W&T Offshore, Inc. (NYSE: WTI) announced today financial and operational results for the third quarter 2006.
-- Third quarter 2006 production is 50% higher than third quarter 2005 and increased 32% sequentially from the second quarter 2006 -- Year-to-date production was at an all-time high and is projected to increase over 50% for 2007 -- W&T was also successful in seven of seven exploration wells, including two on the conventional shelf, four in the deep shelf and one in the deepwater during the third quarter of 2006
Net Income: Net income for the three months ended September 30, 2006 was $66.7 million, or $0.91 per diluted share, on revenue of $213.4 million. Net income for the third quarter of 2006 includes an unrealized gain of $14.8 million (after taxes) related to W&T's open commodity derivative contracts. Without the effect of the unrealized commodity derivative gain, net income for the third quarter of 2006 would have been $51.9 million or $0.71 per diluted share. See "Additional Non-GAAP Information" later in this release. This compares to net income of $53.1 million, or $0.80 per diluted share, on revenues of $153.4 million for the third quarter of 2005. Net income for the nine months ended September 30, 2006 was $161.0 million, or $2.35 per diluted share, or $2.21 per diluted share without the effect of the unrealized commodity derivative gain, on revenues of $536.1 million, compared to net income of $138.2 million or $2.09 per diluted share, on revenues of $432.3 million for 2005. Weighted average shares of common stock outstanding on a diluted basis increased 11% to 73.0 million shares for the third quarter of 2006, compared to third quarter of 2005.
Cash Flow from Operations and EBITDA: EBITDA and Adjusted EBITDA are non- GAAP financial measures and are defined in "Additional Non-GAAP Information" later in this press release. Third quarter 2006 Adjusted EBITDA was $168.5 million, compared to $126.1 million during the prior year's third quarter. Net cash provided by operating activities for the nine months ended September 30, 2006 increased to $351.5 million from $343.9 million in 2005. Adjusted EBITDA was $434.1 million for the nine months ended September 30, 2006, compared to $350.7 million for the prior year period. For more complete information regarding EBITDA and Adjusted EBITDA please see "Additional Non- GAAP Information" later in this press release.
Production and Prices: Total production in the third quarter of 2006 was 15.4 billion cubic feet ("Bcf") of natural gas at an average price of $6.58 per thousand cubic feet ("Mcf") and 1.8 million barrels ("MMBbls") of oil at an average price of $62.08 per Bbl, or 26.2 billion cubic feet of natural gas equivalent ("Bcfe") at an average price of $8.14 per Mcfe. This compares to production of 11.5 Bcf of natural gas at an average price of $8.64 per Mcf and 1.0 MMBbls of oil at an average price of $54.39 per Bbl, or 17.5 Bcfe at an average price of $8.79 per Mcfe in the third quarter of 2005. The increase in volumes is primarily attributable to the additional production associated with the Kerr-McGee transaction closing within the quarter and new production from successful exploration drilling.
For the nine months ended September 30, 2006 total production was 37.5 Bcf of natural gas at an average price of $7.35 per Mcf and 4.3 MMBbls of oil at an average price of $60.48 per Bbl, or 63.3 Bcfe at an average price of $8.46 per Mcfe. This compares to 37.1 Bcf of natural gas at an average price of $7.31 per Mcf and 3.4 MMBbls of oil at an average price of $47.38 per Bbl, or 57.4 Bcfe at an average price of $7.52 per Mcfe for the same period in 2005.
Average realized prices exclude the settlement of commodity derivative contracts that do not qualify for hedge accounting. Had the Company included the effect of the realized cash portion of commodity derivative contracts during the relative periods, the average realized sales price for natural gas would have been $6.87 per Mcf for the third quarter of 2006 and $7.54 per Mcf for the nine months ended September 30, 2006. The average realized sales price for oil would have been $62.00 per barrel for the third quarter of 2006 and $60.33 per barrel for the nine months ended September 30, 2006. On a natural gas equivalent basis, the average realized sales price would have been $8.30 per Mcfe for the third quarter of 2006 and $8.57 per Mcfe for the nine months ended September 30, 2006. The Company did not have any derivative contracts in place during the periods ended in 2005.
Lease Operating Expenses ("LOE"): LOE for the third quarter increased from $18.2 million, or $1.04 per Mcfe, to $34.4 million, or $1.31 per Mcfe in the third quarter of 2006. LOE for the nine months ended September 30, 2006 was $66.5 million, or $1.05 per Mcfe, compared to $52.3 million, or $0.91 per Mcfe, in 2005. The increases in quarterly and year-to-date LOE are primarily attributable to higher costs associated with the Kerr-McGee transaction in August 2006 and increases in insurance premiums as a result of last year's hurricanes, hurricane repair costs, overall service costs, and supply costs at existing properties.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A increased to $85.5 million, or $3.26 per Mcfe, in the third quarter of 2006 from $45.6 million, or $2.61 per Mcfe, in the same period of 2005. DD&A for the nine months ended 2006 was $201.9 million or $3.19 per Mcfe, compared to DD&A of $138.8 million, or $2.42 per Mcfe, for the same period in 2005 as a result of an increase in total depletable costs due to the Kerr-McGee transaction and the Company's higher drilling activities.
Kerr-McGee purchase price allocation: The Kerr-McGee properties were accounted for as a purchase, and accordingly, the results of operations are included in our consolidated statements of operations from the closing date of August 24, 2006. The purchase price was allocated to the acquired assets and assumed liabilities based on their estimated fair value at the time of acquisition. As a result of our allocation, $814 million was allocated to proved oil and gas properties and $392 million was allocated to unproved oil and gas properties.
Capital Expenditures and Operations Update: During the third quarter of 2006, the Company participated in the drilling of seven exploration wells (gross) in the Gulf of Mexico, all of which were successful. W&T also successfully drilled one development well during the period. During the third quarter of 2006, the Company spent $70.3 million for development, $35.4 million for exploration, $1.1 billion for acquisition and other leasehold activity and $3.6 million for other capital items. For the nine months ended September 30, 2006, $198.0 million was spent on development, $167.7 million for exploration, and $1.1 billion for acquisition and other leasehold activity.
As a result of the Company's success, the Company's 2006 capital budget was increased to $550 million from $400 million by the Board of Directors during the third quarter.
Drilling Highlights: In the third quarter of 2006, the Company participated in the drilling of eight wells, seven exploration and one development. Of the wells drilled in the third quarter of 2006, one was in deepwater, four were on the deep shelf, and three were on the conventional shelf. One second-quarter exploration deep shelf well has been re-categorized as non-commercial. Two of the exploration wells, indicated below by an asterisk, were drilled before W&T closed the Kerr-McGee transaction.
Successful Wells: Field Name/Well Category Working Interest % High Island 24L #1 Exploration / Shelf 25% South Timbalier 206 A-10ST Exploration / Shelf 25% Bay Junop S/L 17993-#1 Exploration / Deep Shelf 100% Eugene Island 205 C-3ST Exploration / Deep Shelf 100% South Timbalier 41 #5 (F-1)* Exploration / Deep Shelf 40% West Cameron 295 #4ST* Exploration / Deep Shelf 20% Green Canyon 82 #3 Exploration / Deepwater 100% East Cameron 321 A-25ST Development / Shelf 100% * Indicates wells drilled before W&T closed the Kerr-McGee transaction Non-commercial Well (re-classified from the second quarter): Field Name/Well Category Working Interest % Eugene Island 205 C-1ST Exploration / Deep Shelf 100%
In the remainder of the year, the Company anticipates drilling two exploration wells on the conventional shelf, and two exploration wells in the deepwater.
Dividends: On October 11, 2006, the board of directors declared a cash dividend of $0.03 per common share, which was paid on November 1, 2006 to shareholders of record on October 22, 2006. On August 1, 2006, the Company paid a cash dividend of $0.03 per common share to shareholders of record on July 14, 2006.
Insurance Update: As of September 30, 2006, the Company has incurred $76.8 million of costs, net to its interest, to remediate damage caused by Hurricanes Katrina and Rita that have been reclassified to insurance receivables and other assets. Included in insurance receivables and other assets is $45.7 million and $6.1 million, respectively, which represents the estimated reimbursable hurricane remediation costs incurred in excess of the deductibles that the Company believes are reimbursable under its insurance policies. To date, the Company has received payment for its claims related to Hurricane Rita in the amount of $17.2 million, net of deductibles. The Company estimates the total remediation costs associated with the hurricanes to be between $90 million and $100 million.
Kerr-McGee Transaction Closing: W&T Offshore completed the merger transaction with a Kerr-McGee subsidiary owning the Gulf of Mexico conventional shelf properties of Kerr-McGee. The effective date of the transaction is October 1, 2005. The merger transaction closed on August 24, 2006 for $1.03 billion.
Equity Offering: W&T Offshore completed an equity offering on July 20, 2006, selling a total of 8.5 million shares at $32.50 per share, before underwriting discount. The Company granted the underwriters a 30-day option to purchase up to an additional 1.275 million shares of common stock, which was exercised on August 9, 2006. Total proceeds to the Company, net of underwriting discount, was $308.2 million, which was used as a portion of the cash consideration in the Kerr-McGee merger transaction.
Outlook: Certain factors affecting these forward-looking statements are listed in this news release. Guidance on performance for the fourth quarter, full year 2006 and full year 2007 is shown in the table below. The fourth quarter and full year 2006 guidance includes the impact of the Kerr-McGee transaction, as reported in our operations update on August 28, 2006.
Estimated Production Fourth Quarter Full-Year Full-Year 2006 2006 2007 Crude oil (MMBbls) 2.1 - 2.3 6.4 - 6.6 9.6 - 10.5 Natural gas (Bcf) 22.7 - 24.6 60.2 - 62.1 92.2 - 101.2 Total (Bcfe) 35.0 - 38.1 98.4 - 101.4 149.7 - 164.3 Operating Expenses ($ in Fourth Quarter Full-Year Full-Year millions, except as noted) 2006 2006 2007 Lease operating expenses $35.5 - $42.6 $99.7 - $106.8 N/A Gathering, transportation & production taxes $8.1 - $9.6 $19.8 - $21.3 N/A General and administrative $10.2 - $14.2 $40.6 - $44.6 N/A Income tax rate, % deferred 35.0%, 80% 35.0%, 80% N/A
Conference Call Information: W&T will hold a conference call to discuss financial and operational results on Thursday, November 9, 2006 at 10:00 a.m. Eastern Time / 9:00 a.m. Central Time. To participate, dial (303) 262-2075 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, November 16, 2006, and may be accessed by calling (303) 590-3000 and using the pass code 11074827.
About W&T Offshore
Founded in 1983, W&T Offshore is an independent oil and natural gas company focused primarily in the Gulf of Mexico, including exploration in the deepwater, where it has developed significant technical expertise. W&T has grown through acquisition, exploitation and exploration and now holds working interests in over 200 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
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, 2005 (www.sec.gov).
W&T OFFSHORE, INC. Consolidated Statements of Income (In thousands, except per share amounts) (Unaudited) Three Months Ended Nine Months Ended September 30, September 30, 2006 2005 2006 2005 Revenues: Oil and natural gas $213,393 $153,355 $535,960 $431,744 Other 38 70 122 532 Total revenues 213,431 153,425 536,082 432,276 Expenses: Lease operating 34,427 18,226 66,491 52,253 Gathering, transportation costs and production taxes 5,186 2,551 11,694 10,186 Depreciation, depletion, and amortization 82,142 43,403 194,052 131,967 Asset retirement obligation accretion 3,324 2,203 7,840 6,829 General and administrative 9,645 6,524 30,377 19,187 Commodity derivative gain (27,065) - (21,793) - Total operating expenses 107,659 72,907 288,661 220,422 Income from operations 105,772 80,518 247,421 211,854 Net interest income (expense) (3,627) 581 (871) 468 Income before income taxes 102,145 81,099 246,550 212,322 Income tax expense 35,444 27,997 85,553 74,156 Net income $66,701 $53,102 $160,997 $138,166 Earnings per common share: Basic $0.92 $0.80 $2.36 $2.14 Diluted $0.91 $0.80 $2.35 $2.09 Weighted average shares outstanding: Basic 72,882 65,970 68,300 64,649 Diluted 73,039 65,970 68,412 65,968 Consolidated Cash Flow Information Net cash provided by operating activities $123,364 $145,342 $351,468 $343,894 Capital expenditures $1,181,423 $82,488 $1,455,800 $227,822 Other Financial Information Adjusted EBITDA $168,524 $126,124 $434,089 $350,650 W&T OFFSHORE, INC. Operating Data (Unaudited) Three Months Nine Months Ended Ended September 30, June 30, 2006 2005 2006 2005 Net sales: Natural gas (MMcf) 15,374 11,498 37,490 37,150 Oil (MBbls) 1,809 993 4,307 3,379 Total natural gas and oil (MMcfe) 26,228 17,456 63,333 57,421 Average daily equivalent sales (MMcfe/d) 285 190 232 210 Average realized sales prices: Natural gas ($/Mcf) $6.58 $8.64 $7.35 $7.31 Oil ($/Bbl) 62.08 54.39 60.48 47.38 Natural gas equivalent ($/Mcfe) 8.14 8.79 8.46 7.52 Average per Mcfe data ($/Mcfe): Lease operating expenses $1.31 $1.04 $1.05 $0.91 Gathering, transportation cost and production taxes 0.20 0.15 0.18 0.18 Depreciation, depletion, amortization and accretion 3.26 2.61 3.19 2.42 General and administrative 0.37 0.37 0.48 0.33 Net cash provided by operating activities 4.70 8.33 5.55 5.99 Adjusted EBITDA 6.43 7.23 6.85 6.11 W&T OFFSHORE, INC. Consolidated Balance Sheets (In thousands) (Unaudited) September 30, December 31, 2006 2005 Assets Current assets: Cash $12,071 $187,698 Receivables 159,551 83,623 Prepaid expenses and other 56,298 12,503 Total current assets 227,920 283,824 Property and equipment - at cost 3,082,452 1,486,865 Less accumulated depreciation, depletion and amortization 911,635 717,583 Net property and equipment 2,170,817 769,282 Other assets 23,088 11,414 Total assets $2,421,825 $1,064,520 Liabilities and Shareholders' Equity Current liabilities: Current portion of LT Debt $354,640 $- Accounts payable 169,936 143,049 Asset retirement obligations 43,760 39,653 Accrued liabilities and other 80,211 48,990 Total current liabilities 648,547 231,692 Long-term debt, less current portion 316,233 40,000 Asset retirement obligations, less current portion 243,858 112,621 Deferred income taxes 199,964 134,395 Other liabilities 4,398 2,429 Shareholders' equity: Common stock 1 1 Additional paid-in capital 361,489 52,332 Retained earnings 648,080 491,050 Accumulated other comprehensive income (loss) (745) - Total shareholders' equity 1,008,825 543,383 Total liabilities and shareholders' equity $2,421,825 $1,064,520 W&T OFFSHORE, INC. Consolidated Statements of Cash Flows (In thousands) (Unaudited) Nine Months Ended September 30, 2006 2005 Operating activities: Net income $160,997 $138,166 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation, depletion, amortization and accretion 201,892 138,796 Amortization of debt issuance costs 1,097 262 Accretion of discount on long-term debt 2,141 - Share-based compensation 2,177 390 Unrealized commodity derivative gain (15,224) - Deferred income taxes 65,977 32,517 Changes in operating assets and liabilities (67,589) 33,763 Net cash provided by operating activities 351,468 343,894 Investing activities: Investment in oil and gas property and equipment, net (1,449,095) (227,464) Investment in marketable securities - (1,822) Purchases of furniture, fixtures and other (6,705) (358) Change in restricted deposits (280) (187) Net cash used in investing activities (1,456,080) (229,831) Financing activities: Borrowings of long-term debt 819,732 2,550 Repayments of borrowings of long- term debt (191,000) (37,550) Proceeds from equity offering, net of costs 306,980 - Dividends to shareholders (5,947) (2,639) Debt issuance costs (780) (889) Net cash provided by (used in) financing activities 928,985 (38,528) (Decrease) increase in cash and cash equivalents (175,627) 75,535 Cash and cash equivalents, beginning of period 187,698 64,975 Cash and cash equivalents, end of period $12,071 $140,510 W&T OFFSHORE, INC. Additional 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", and "Adjusted EBITDA". 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 to Adjusted Net Income "Adjusted Net Income" does not include the unrealized derivative gain and associated tax effects. Adjusted Net Income 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 period to prior periods. Three Months Ended Nine Months Ended September 30, September 30, 2006 2005 2006 2005 (In thousands, except per share amounts) (Unaudited) Net income $66,701 $53,102 $160,997 $138,166 Less: Unrealized commodity derivative gain (22,714) - (15,224) - Plus: Income tax adjustment for above item 7,882 - 5,283 - Earnings stated without effect of the above items $51,869 $53,102 $151,056 $138,166 Earnings per share- diluted without the effect of the above items $0.71 $0.80 $2.21 $2.09 Reconciliation of Net Income to EBITDA
EBITDA is defined as net income plus income tax expense, net interest (income) expense, depreciation, depletion, amortization and accretion and non- cash expenses associated with unrealized changes in the fair market value of open derivative contracts. Although not prescribed under GAAP, we believe the presentation of EBITDA is relevant and useful because it helps our investors understand our operating performance and makes it easier to compare our results with those of other companies that have different financing, capital or tax structures. 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, as we calculate it, may not be comparable to EBITDA measures reported by other companies. In addition, EBITDA does not represent funds available for discretionary use. "Adjusted EBITDA" excludes the unrealized gain or loss related to open derivative contracts. Adjusted EBITDA excludes certain non- cash items that management believes affect the comparability of operating results.
The following table presents a reconciliation of our consolidated net income to consolidated EBITDA.
Three Months Ended Nine Months Ended September 30, September 30, 2006 2005 2006 2005 (In thousands) (Unaudited) Net income $66,701 $53,102 $160,997 $138,166 Income tax expense 35,444 27,997 85,553 74,156 Net interest (income) expense 3,627 (581) 871 (468) Depreciation, depletion, amortization and accretion 85,466 45,606 201,892 138,796 EBITDA 191,238 126,124 449,313 350,650 Adjustments: Non-cash change in unrealized commodity derivatives (before tax) (22,714) - (15,224) - Adjusted EBITDA $168,524 $126,124 $434,089 $350,650
Manuel Mondragon, Vice President of Finance
Ken Dennard / email@example.com
Lisa Elliott / firstname.lastname@example.org
DRG&E / 713-529-6600
SOURCE W&T Offshore, Inc.