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Profile
W&T Offshore Inc.
Nine Greenway Plaza
Suite 300
Houston, TX 77046-0905
United States - Map
Phone: 713-626-8525
Fax: 713-626-8527
Website: W&T Offshore
Details
Index Membership: N/A
Sector: Basic Materials
Industry: Oil & Gas Drilling & Exploration
Full Time Employees: 286
Business Summary
W&T Offshore, Inc., together with its subsidiaries, engages in the acquisition, exploitation, exploration, production, and development of oil and natural gas properties in the Gulf of Mexico. It has interests in approximately 77 producing fields in federal and state waters; leases covering approximately 0.6 million net acres in the outer continental shelf off the coasts of Louisiana, Texas, Mississippi, and Alabama; and interests in approximately 288 structures. As of December 31, 2009, the company had proved reserves of 371.0 billion cubic feet of gas equivalent. W&T Offshore, Inc. was founded in 1983 and is based in Houston, Texas.
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Valuation Measures
Market Cap (intraday)5: 1.58B
Enterprise Value (Mar 2, 2011)3: 2.11B
Trailing P/E (ttm, intraday): 9.78
Forward P/E (fye Dec 31, 2011)1: 14.52
PEG Ratio (5 yr expected)1: N/A
Price/Sales (ttm): 2.65
Price/Book (mrq): 3.94
Enterprise Value/Revenue (ttm)3: 3.03
Enterprise Value/EBITDA (ttm)3: 4.52
Financial Highlights
Fiscal Year
Fiscal Year Ends: Dec 31
Most Recent Quarter (mrq): Sep 30, 2010
Profitability
Profit Margin (ttm): 23.22%
Operating Margin (ttm): 24.13%
Management Effectiveness
Return on Assets (ttm): 7.01%
Return on Equity (ttm): 41.44%
Income Statement
Revenue (ttm): 694.93M
Revenue Per Share (ttm): 9.42
Qtrly Revenue Growth (yoy): 1.50%
Gross Profit (ttm): 393.46M
EBITDA (ttm): 466.55M
Net Income Avl to Common (ttm): 160.02M
Diluted EPS (ttm): 2.17
Qtrly Earnings Growth (yoy): N/A
Balance Sheet
Total Cash (mrq): 180.51M
Total Cash Per Share (mrq): 2.42
Total Debt (mrq): 450.00M
Total Debt/Equity (mrq): 99.46
Current Ratio (mrq): 1.34
Book Value Per Share (mrq): 6.25
Cash Flow Statement
Operating Cash Flow (ttm): 457.27M
Levered Free Cash Flow (ttm): 174.84M
Trading Information
Stock Price History
Beta: 1.62
52-Week Change3: 169.88%
S&P500 52-Week Change3: 16.81%
52-Week High (Feb 28, 2011)3: 26.12
52-Week Low (Mar 26, 2010)3: 8.24
50-Day Moving Average3: 21.02
200-Day Moving Average3: 15.10
Share Statistics
Avg Vol (3 month)3: 872,181
Avg Vol (10 day)3: 878,650
Shares Outstanding5: 74.63M
Float: 34.86M
% Held by Insiders6: 53.24%
% Held by Institutions6: 50.50%
Shares Short (as of Feb 15, 2011)3: 9.83M
Short Ratio (as of Feb 15, 2011)3: 14.10
Short % of Float (as of Feb 15, 2011)3: 36.00%
Shares Short (prior month)3: 10.26M
Dividends & Splits
Forward Annual Dividend Rate4: 0.16
Forward Annual Dividend Yield4: 0.60%
Trailing Annual Dividend Yield3: 0.14
Trailing Annual Dividend Yield3: 0.60%
5 Year Average Dividend Yield4: 0.60%
Payout Ratio4: 7.00%
Dividend Date3: Dec 28, 2010
Ex-Dividend Date4: Dec 17, 2010
Last Split Factor (new per old)2: N/A
Last Split Date3: N/A
WTI Key Statistics | W&T Offshore, Inc. Common Stock Stock - Yahoo! Finance
sell off su risultati trimestrali, smaltiscono un eccesso accumulato nel tempo secondo me, in watch
W&T Offshore Reports Fourth Quarter and Full Year 2010 Financial and Operational Results - Yahoo! Finance
Press Release Source: W&T Offshore, Inc. On Wednesday March 2, 2011, 6:15 am EST
HOUSTON, March 2, 2011 /PRNewswire/ -- W&T Offshore, Inc. (NYSE:WTI - News) today announces financial and operational results for the fourth quarter and full year 2010. Some of the highlights include:
•Total proved reserve replacement was 231%. Proved reserves increased 31% from 371.0 Bcfe to 485.4 Bcfe. Oil and natural gas liquids comprise 47% of total proved reserves. Year-end 2010 proved developed reserves increased to 81% of total proved reserves from 76% in 2009. Our PV-10 increased 68% over year-end 2009.
•During the fourth quarter, we acquired three deepwater properties from Shell Offshore Inc. at a cost of $10.49 per barrel equivalent or $1.75 per Mcfe for proved reserves.
•For the full year 2010, net income increased by $305.8 million to $117.9 million from a net loss of ($187.9) million in 2009. Earnings per share increased $4.09 per share to $1.58 per share in 2010 from a loss in 2009 of ($2.51) per share. Earnings for the year 2010, adjusted to exclude special items, were $1.57 per share compared to a loss of ($1.10) in 2009.
•Cash flow from operating activities for the full year 2010 increased $308.5 million, or 197%, to $464.8 million compared to $156.3 million in 2009. Adjusted EBITDA increased by $108.8 million to $450.2 million in 2010 compared to $341.4 million in 2009 and Adjusted EBITDA margin increased to 64% in 2010 compared to 56% in 2009.
•Earnings for the fourth quarter, adjusted to exclude special items, were $0.40 per share compared to $0.35 in the fourth quarter of the prior year. Fourth quarter net income was $20.5 million and earnings per share were $0.27.
•Drilled the successful Main Pass 108 E-3 well that found 300 feet of net vertical pay in six sands. This is a conventional shelf exploration well and we have a 100% working interest.
•After the close of the fourth quarter, the Company drilled two wells. One of the wells is an onshore well in Southeast Texas in which we own a 50% non-operated working interest. The well found 22 feet of gas condensate pay, and we expect it to be online before the end of the first quarter of 2011. The second well is the Main Pass 180 A-2 well in which we own a 100% working interest. The well reached a total vertical depth of 13,950 feet and found approximately 91 feet of high quality gas sands in three separate zones.
Tracy W. Krohn, Chairman and Chief Executive Officer, commented, "We had another great quarter with solid production, high realized oil prices, good earnings and cash flow. We were able to increase reserves in 2010 with two different acquisitions, which we expect to lead to increased production in 2011 as a result. We funded our entire capital expenditure program, including both acquisitions, with internally generated cash flow. As a result, we did not have to increase our debt levels nor did we need to sell any equity to accomplish these transactions. As we have historically indicated, we manage for cash and constantly seek acquisition and joint venture opportunities. We believe there continue to be important growth opportunities in the market place that will make sense for us and allow us to grow reserves and production and increase shareholder value. Our liquidity continues to be very strong, allowing us the ability to complete acquisitions when the right opportunity comes along."
Revenues, Net Income and EPS: Net income for the fourth quarter of 2010 excluding special items was $29.6 million, or $0.40 per share. This compares to $26.7 million, or $0.35 per common share, reported for the fourth quarter of 2009, excluding special items. See the "Reconciliation of Net Income (Loss) to Net Income (Loss) Excluding Special Items" and related earnings per share, excluding special items table under "Non-GAAP Financial Information" at the back of this press release for a description of the special items.
Net income for the fourth quarter of 2010 was $20.5 million, or $0.27 per common share, on revenues of $187.0 million, compared to net income of $64.0 million and earnings per share of $0.84 on revenues of $176.1 million for the same period in 2009. Net income in the fourth quarter of 2009 benefitted from a one-time $38.4 million tax benefit due to tax legislation adopted in 2009. The Worker, Homeownership and Business Assistance Act of 2009, which extended the net operating loss carry-back period from two years to five years, resulted in additional tax benefits to us. Revenues were higher in the fourth quarter of 2010 due to higher realized oil prices and minimal changes in production.
Net income for 2010 was $117.9 million, or $1.58 per share, on revenues of $705.8 million. This compares to a net loss in 2009 of ($187.9) million, or ($2.51) loss per share, on revenues of $611.0 million. Net income for the year 2010, excluding special items, was $116.7 million, or $1.57 per share. For 2009, the net loss, excluding special items, was ($82.3) million, or ($1.10) loss per common share. The dramatic increase in earnings between periods is primarily due to an increase in our average realized sales prices, mainly due to oil price increases, and a reduction in most of our expenses. In addition, the 2009 period included a ceiling test impairment of $218.9 million. For 2010, lease operating expenses ("LOE"), depreciation, depletion, amortization and accretion ("DD&A") and the derivative loss were all lower, the reasons for which are explained below.
Cash Flow from Operating Activities and Adjusted EBITDA: EBITDA and Adjusted EBITDA, and Adjusted EBITDA margin are non-GAAP financial measures and are defined and reconciled in "Non-GAAP Financial Information" later in this press release. Adjusted EBITDA for the fourth quarter of 2010 was $121.6 million compared to $115.1 million during the fourth quarter of the prior year. Adjusted EBITDA for the fourth quarter of 2010 benefitted from higher averaged realized sales prices.
For 2010, Adjusted EBITDA was $450.2 million, an increase of 32% compared to $341.4 million for the year 2009. Net cash provided by operating activities for the full year of 2010 was $464.8 million, a significant increase over the $156.3 million reported for the prior year. The dramatic increase in cash flow was due to higher prices, lower operating expenses, a federal income tax refund of $99.8 million and insurance reimbursements of $65.5 million.
Production and Prices: During the fourth quarter of 2010, we sold 1.8 million barrels of oil and natural gas liquids at an average realized sales price of $77.27 per barrel and 11.9 Bcf of natural gas at an average realized sales price of $4.01 per Mcfe. In total we sold 22.6 Bcfe at an average realized sales price of $8.23 per Mcfe compared to 22.9 Bcfe sold at an average price of $7.67 per Mcfe, in the fourth quarter of the prior year. Production volumes were negatively affected in 2010 because of production shut in at our MP 108 field due to a third party pipeline outage that has continued since early June 2010.
For the year 2010, we sold 7.1 million barrels of oil and natural gas liquids at an average realized sales price of $71.65 per barrel and 44.7 Bcf of natural gas at an average realized sales price of $4.55 per Mcf. In total we sold 87.0 Bcfe at an average realized sales price of $8.15 per Mcfe, compared to 94.8 Bcfe sold at an average price of $6.39 per Mcfe in 2009. The 8% decline in production is largely attributable to divestitures completed in 2009, the production shut in at our MP 108 field, as well as natural reservoir declines, somewhat offset by partial year production from the newly acquired properties from Shell and Total.
Lease Operating Expenses: For the fourth quarter of 2010, total LOE was $47.5 million, up slightly from $45.8 million reported in the prior year's fourth quarter. Despite adding the Shell deepwater properties, most of the components of LOE were lower in 2010 compared to 2009 with the exception of one notable item. Facilities costs, which is a component of LOE, increased $6.8 million, about 40% of which can be attributed to repairs to newly acquired properties, while the remainder relates to pipeline and compressor repairs and blast and paint work. Also of note, for both the fourth quarter of 2010 and the fourth quarter of 2009, insurance reimbursements exceeded hurricane remediation costs that are included in LOE. The reduction in LOE as a result of these items was greater in the fourth quarter of 2009 than the comparable 2010 amount. Insurance premiums that are included in LOE decreased $3.4 million in the fourth quarter of 2010 compared to the fourth quarter of 2009 due to a policy renewal effective June 1, 2010 covering well control and hurricane damage.
LOE for the year 2010 was $169.7 million, or $1.95 per Mcfe, down considerably from the $203.9 million, or $2.15 per Mcfe, reported for the prior year. LOE decreased for the year 2010 due to the 2009 property divestitures and the significant reduction in hurricane repairs, net of insurance reimbursements in 2010 compared to 2009. Included in lease operating expenses for 2010 is a net reduction to LOE of $11.7 million (insurance reimbursements exceeded hurricane remediation costs). This compares to an increase to LOE of $18.4 million for hurricane remediation costs in excess of insurance reimbursements in the prior year. Increases to LOE for the year were the costs to operate the new properties, higher workover expenditures associated with rig activity to perform certain workovers and greater facilities work associated with the new properties.
Depreciation, depletion, amortization and accretion: DD&A decreased to $73.6 million, or $3.25 per Mcfe, in the fourth quarter of 2010 compared to $78.3 million, or $3.42 per Mcfe, in the fourth quarter of the prior year. DD&A for the year 2010 was $294.1 million, or $3.38 per Mcfe, compared to $342.5 million, or $3.61 per Mcfe, for the year 2009. DD&A is lower due to lower production volumes and an increase in proved reserves.
Capital Expenditures, Acquisitions and Operations Update: For 2010, our capital expenditures excluding acquisitions were $178.7 million and our expenditures for acquisitions were $236.9 million. Acquisitions included $115.0 million to acquire the Total properties and $121.9 million to acquire the Shell properties. Other capital expenditures were made up of $60.2 million for exploration activities, $77.2 million for development activities and $41.4 million for seismic, leasehold and other costs. Capital expenditures and acquisitions for 2010 were funded from cash flow from operating activities and cash on hand. Capital expenditures in 2009 were $276.1 million, and no significant acquisitions were completed in 2009.
During 2010, we participated in the drilling of six offshore and two onshore wells. Five of the six offshore wells were successful, but neither of the onshore wells, which were both high risk but high potential exploration opportunities, were commercial. All five of the successful wells were on the conventional shelf and four were exploration wells and one was a development well. We operate three of the five successful wells.
Drilling Highlights: In the fourth quarter of 2010, the Company drilled the Main Pass 108 E-3 well. This well logged over 300 feet of net vertical pay in six sands. This is a conventional shelf exploration well in which we own a 100% working interest.
After the close of the fourth quarter, the Company drilled two wells. One of the wells is an onshore well in Southeast Texas in which we own a 50% non-operated working interest. The well found 22 feet of gas condensate pay, and we expect it to be online before the end of the first quarter of 2011. The second well is the Main Pass 180 A-2 well in which we own a 100% working interest. The well reached a total vertical depth of 13,950 feet and found approximately 91 feet of high quality gas sands in three separate zones.
Reserves: At December 31, 2010, total proved reserves were 485.4 Bcfe, compared to proved reserves of 371.0 Bcfe at the end of 2009. The 31% increase in proved reserves is primarily due to the newly acquired properties from Shell and Total, success with the drill bit and positive revisions, which are partially offset by production. Year-end 2010 proved reserves are comprised of 53% natural gas and 47% oil and natural gas liquids based on a ratio of six Mcf to one barrel equivalent. In accordance with guidelines established by the SEC, our proved reserves as of December 31, 2010 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 2010 through December 2010. The present value of our total proved reserves only, discounted at 10% (referred to as "PV-10"*) was $1.9 billion at December 31, 2010 excluding the effect of estimated asset retirement obligations. PV-10, including estimated asset retirement obligations, was $1.5 billion. This is based on average prices of $4.38 per Mcf for natural gas and $75.96 per Bbl for oil and natural gas liquids, adjusted 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 is defined in the "Non-GAAP Financial Information" later in this press release.
The Company's proved reserves are summarized in the table below:
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W&T Offshore Inc.
Nine Greenway Plaza
Suite 300
Houston, TX 77046-0905
United States - Map
Phone: 713-626-8525
Fax: 713-626-8527
Website: W&T Offshore
Details
Index Membership: N/A
Sector: Basic Materials
Industry: Oil & Gas Drilling & Exploration
Full Time Employees: 286
Business Summary
W&T Offshore, Inc., together with its subsidiaries, engages in the acquisition, exploitation, exploration, production, and development of oil and natural gas properties in the Gulf of Mexico. It has interests in approximately 77 producing fields in federal and state waters; leases covering approximately 0.6 million net acres in the outer continental shelf off the coasts of Louisiana, Texas, Mississippi, and Alabama; and interests in approximately 288 structures. As of December 31, 2009, the company had proved reserves of 371.0 billion cubic feet of gas equivalent. W&T Offshore, Inc. was founded in 1983 and is based in Houston, Texas.
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Valuation Measures
Market Cap (intraday)5: 1.58B
Enterprise Value (Mar 2, 2011)3: 2.11B
Trailing P/E (ttm, intraday): 9.78
Forward P/E (fye Dec 31, 2011)1: 14.52
PEG Ratio (5 yr expected)1: N/A
Price/Sales (ttm): 2.65
Price/Book (mrq): 3.94
Enterprise Value/Revenue (ttm)3: 3.03
Enterprise Value/EBITDA (ttm)3: 4.52
Financial Highlights
Fiscal Year
Fiscal Year Ends: Dec 31
Most Recent Quarter (mrq): Sep 30, 2010
Profitability
Profit Margin (ttm): 23.22%
Operating Margin (ttm): 24.13%
Management Effectiveness
Return on Assets (ttm): 7.01%
Return on Equity (ttm): 41.44%
Income Statement
Revenue (ttm): 694.93M
Revenue Per Share (ttm): 9.42
Qtrly Revenue Growth (yoy): 1.50%
Gross Profit (ttm): 393.46M
EBITDA (ttm): 466.55M
Net Income Avl to Common (ttm): 160.02M
Diluted EPS (ttm): 2.17
Qtrly Earnings Growth (yoy): N/A
Balance Sheet
Total Cash (mrq): 180.51M
Total Cash Per Share (mrq): 2.42
Total Debt (mrq): 450.00M
Total Debt/Equity (mrq): 99.46
Current Ratio (mrq): 1.34
Book Value Per Share (mrq): 6.25
Cash Flow Statement
Operating Cash Flow (ttm): 457.27M
Levered Free Cash Flow (ttm): 174.84M
Trading Information
Stock Price History
Beta: 1.62
52-Week Change3: 169.88%
S&P500 52-Week Change3: 16.81%
52-Week High (Feb 28, 2011)3: 26.12
52-Week Low (Mar 26, 2010)3: 8.24
50-Day Moving Average3: 21.02
200-Day Moving Average3: 15.10
Share Statistics
Avg Vol (3 month)3: 872,181
Avg Vol (10 day)3: 878,650
Shares Outstanding5: 74.63M
Float: 34.86M
% Held by Insiders6: 53.24%
% Held by Institutions6: 50.50%
Shares Short (as of Feb 15, 2011)3: 9.83M
Short Ratio (as of Feb 15, 2011)3: 14.10
Short % of Float (as of Feb 15, 2011)3: 36.00%
Shares Short (prior month)3: 10.26M
Dividends & Splits
Forward Annual Dividend Rate4: 0.16
Forward Annual Dividend Yield4: 0.60%
Trailing Annual Dividend Yield3: 0.14
Trailing Annual Dividend Yield3: 0.60%
5 Year Average Dividend Yield4: 0.60%
Payout Ratio4: 7.00%
Dividend Date3: Dec 28, 2010
Ex-Dividend Date4: Dec 17, 2010
Last Split Factor (new per old)2: N/A
Last Split Date3: N/A
WTI Key Statistics | W&T Offshore, Inc. Common Stock Stock - Yahoo! Finance
sell off su risultati trimestrali, smaltiscono un eccesso accumulato nel tempo secondo me, in watch
W&T Offshore Reports Fourth Quarter and Full Year 2010 Financial and Operational Results - Yahoo! Finance
Press Release Source: W&T Offshore, Inc. On Wednesday March 2, 2011, 6:15 am EST
HOUSTON, March 2, 2011 /PRNewswire/ -- W&T Offshore, Inc. (NYSE:WTI - News) today announces financial and operational results for the fourth quarter and full year 2010. Some of the highlights include:
•Total proved reserve replacement was 231%. Proved reserves increased 31% from 371.0 Bcfe to 485.4 Bcfe. Oil and natural gas liquids comprise 47% of total proved reserves. Year-end 2010 proved developed reserves increased to 81% of total proved reserves from 76% in 2009. Our PV-10 increased 68% over year-end 2009.
•During the fourth quarter, we acquired three deepwater properties from Shell Offshore Inc. at a cost of $10.49 per barrel equivalent or $1.75 per Mcfe for proved reserves.
•For the full year 2010, net income increased by $305.8 million to $117.9 million from a net loss of ($187.9) million in 2009. Earnings per share increased $4.09 per share to $1.58 per share in 2010 from a loss in 2009 of ($2.51) per share. Earnings for the year 2010, adjusted to exclude special items, were $1.57 per share compared to a loss of ($1.10) in 2009.
•Cash flow from operating activities for the full year 2010 increased $308.5 million, or 197%, to $464.8 million compared to $156.3 million in 2009. Adjusted EBITDA increased by $108.8 million to $450.2 million in 2010 compared to $341.4 million in 2009 and Adjusted EBITDA margin increased to 64% in 2010 compared to 56% in 2009.
•Earnings for the fourth quarter, adjusted to exclude special items, were $0.40 per share compared to $0.35 in the fourth quarter of the prior year. Fourth quarter net income was $20.5 million and earnings per share were $0.27.
•Drilled the successful Main Pass 108 E-3 well that found 300 feet of net vertical pay in six sands. This is a conventional shelf exploration well and we have a 100% working interest.
•After the close of the fourth quarter, the Company drilled two wells. One of the wells is an onshore well in Southeast Texas in which we own a 50% non-operated working interest. The well found 22 feet of gas condensate pay, and we expect it to be online before the end of the first quarter of 2011. The second well is the Main Pass 180 A-2 well in which we own a 100% working interest. The well reached a total vertical depth of 13,950 feet and found approximately 91 feet of high quality gas sands in three separate zones.
Tracy W. Krohn, Chairman and Chief Executive Officer, commented, "We had another great quarter with solid production, high realized oil prices, good earnings and cash flow. We were able to increase reserves in 2010 with two different acquisitions, which we expect to lead to increased production in 2011 as a result. We funded our entire capital expenditure program, including both acquisitions, with internally generated cash flow. As a result, we did not have to increase our debt levels nor did we need to sell any equity to accomplish these transactions. As we have historically indicated, we manage for cash and constantly seek acquisition and joint venture opportunities. We believe there continue to be important growth opportunities in the market place that will make sense for us and allow us to grow reserves and production and increase shareholder value. Our liquidity continues to be very strong, allowing us the ability to complete acquisitions when the right opportunity comes along."
Revenues, Net Income and EPS: Net income for the fourth quarter of 2010 excluding special items was $29.6 million, or $0.40 per share. This compares to $26.7 million, or $0.35 per common share, reported for the fourth quarter of 2009, excluding special items. See the "Reconciliation of Net Income (Loss) to Net Income (Loss) Excluding Special Items" and related earnings per share, excluding special items table under "Non-GAAP Financial Information" at the back of this press release for a description of the special items.
Net income for the fourth quarter of 2010 was $20.5 million, or $0.27 per common share, on revenues of $187.0 million, compared to net income of $64.0 million and earnings per share of $0.84 on revenues of $176.1 million for the same period in 2009. Net income in the fourth quarter of 2009 benefitted from a one-time $38.4 million tax benefit due to tax legislation adopted in 2009. The Worker, Homeownership and Business Assistance Act of 2009, which extended the net operating loss carry-back period from two years to five years, resulted in additional tax benefits to us. Revenues were higher in the fourth quarter of 2010 due to higher realized oil prices and minimal changes in production.
Net income for 2010 was $117.9 million, or $1.58 per share, on revenues of $705.8 million. This compares to a net loss in 2009 of ($187.9) million, or ($2.51) loss per share, on revenues of $611.0 million. Net income for the year 2010, excluding special items, was $116.7 million, or $1.57 per share. For 2009, the net loss, excluding special items, was ($82.3) million, or ($1.10) loss per common share. The dramatic increase in earnings between periods is primarily due to an increase in our average realized sales prices, mainly due to oil price increases, and a reduction in most of our expenses. In addition, the 2009 period included a ceiling test impairment of $218.9 million. For 2010, lease operating expenses ("LOE"), depreciation, depletion, amortization and accretion ("DD&A") and the derivative loss were all lower, the reasons for which are explained below.
Cash Flow from Operating Activities and Adjusted EBITDA: EBITDA and Adjusted EBITDA, and Adjusted EBITDA margin are non-GAAP financial measures and are defined and reconciled in "Non-GAAP Financial Information" later in this press release. Adjusted EBITDA for the fourth quarter of 2010 was $121.6 million compared to $115.1 million during the fourth quarter of the prior year. Adjusted EBITDA for the fourth quarter of 2010 benefitted from higher averaged realized sales prices.
For 2010, Adjusted EBITDA was $450.2 million, an increase of 32% compared to $341.4 million for the year 2009. Net cash provided by operating activities for the full year of 2010 was $464.8 million, a significant increase over the $156.3 million reported for the prior year. The dramatic increase in cash flow was due to higher prices, lower operating expenses, a federal income tax refund of $99.8 million and insurance reimbursements of $65.5 million.
Production and Prices: During the fourth quarter of 2010, we sold 1.8 million barrels of oil and natural gas liquids at an average realized sales price of $77.27 per barrel and 11.9 Bcf of natural gas at an average realized sales price of $4.01 per Mcfe. In total we sold 22.6 Bcfe at an average realized sales price of $8.23 per Mcfe compared to 22.9 Bcfe sold at an average price of $7.67 per Mcfe, in the fourth quarter of the prior year. Production volumes were negatively affected in 2010 because of production shut in at our MP 108 field due to a third party pipeline outage that has continued since early June 2010.
For the year 2010, we sold 7.1 million barrels of oil and natural gas liquids at an average realized sales price of $71.65 per barrel and 44.7 Bcf of natural gas at an average realized sales price of $4.55 per Mcf. In total we sold 87.0 Bcfe at an average realized sales price of $8.15 per Mcfe, compared to 94.8 Bcfe sold at an average price of $6.39 per Mcfe in 2009. The 8% decline in production is largely attributable to divestitures completed in 2009, the production shut in at our MP 108 field, as well as natural reservoir declines, somewhat offset by partial year production from the newly acquired properties from Shell and Total.
Lease Operating Expenses: For the fourth quarter of 2010, total LOE was $47.5 million, up slightly from $45.8 million reported in the prior year's fourth quarter. Despite adding the Shell deepwater properties, most of the components of LOE were lower in 2010 compared to 2009 with the exception of one notable item. Facilities costs, which is a component of LOE, increased $6.8 million, about 40% of which can be attributed to repairs to newly acquired properties, while the remainder relates to pipeline and compressor repairs and blast and paint work. Also of note, for both the fourth quarter of 2010 and the fourth quarter of 2009, insurance reimbursements exceeded hurricane remediation costs that are included in LOE. The reduction in LOE as a result of these items was greater in the fourth quarter of 2009 than the comparable 2010 amount. Insurance premiums that are included in LOE decreased $3.4 million in the fourth quarter of 2010 compared to the fourth quarter of 2009 due to a policy renewal effective June 1, 2010 covering well control and hurricane damage.
LOE for the year 2010 was $169.7 million, or $1.95 per Mcfe, down considerably from the $203.9 million, or $2.15 per Mcfe, reported for the prior year. LOE decreased for the year 2010 due to the 2009 property divestitures and the significant reduction in hurricane repairs, net of insurance reimbursements in 2010 compared to 2009. Included in lease operating expenses for 2010 is a net reduction to LOE of $11.7 million (insurance reimbursements exceeded hurricane remediation costs). This compares to an increase to LOE of $18.4 million for hurricane remediation costs in excess of insurance reimbursements in the prior year. Increases to LOE for the year were the costs to operate the new properties, higher workover expenditures associated with rig activity to perform certain workovers and greater facilities work associated with the new properties.
Depreciation, depletion, amortization and accretion: DD&A decreased to $73.6 million, or $3.25 per Mcfe, in the fourth quarter of 2010 compared to $78.3 million, or $3.42 per Mcfe, in the fourth quarter of the prior year. DD&A for the year 2010 was $294.1 million, or $3.38 per Mcfe, compared to $342.5 million, or $3.61 per Mcfe, for the year 2009. DD&A is lower due to lower production volumes and an increase in proved reserves.
Capital Expenditures, Acquisitions and Operations Update: For 2010, our capital expenditures excluding acquisitions were $178.7 million and our expenditures for acquisitions were $236.9 million. Acquisitions included $115.0 million to acquire the Total properties and $121.9 million to acquire the Shell properties. Other capital expenditures were made up of $60.2 million for exploration activities, $77.2 million for development activities and $41.4 million for seismic, leasehold and other costs. Capital expenditures and acquisitions for 2010 were funded from cash flow from operating activities and cash on hand. Capital expenditures in 2009 were $276.1 million, and no significant acquisitions were completed in 2009.
During 2010, we participated in the drilling of six offshore and two onshore wells. Five of the six offshore wells were successful, but neither of the onshore wells, which were both high risk but high potential exploration opportunities, were commercial. All five of the successful wells were on the conventional shelf and four were exploration wells and one was a development well. We operate three of the five successful wells.
Drilling Highlights: In the fourth quarter of 2010, the Company drilled the Main Pass 108 E-3 well. This well logged over 300 feet of net vertical pay in six sands. This is a conventional shelf exploration well in which we own a 100% working interest.
After the close of the fourth quarter, the Company drilled two wells. One of the wells is an onshore well in Southeast Texas in which we own a 50% non-operated working interest. The well found 22 feet of gas condensate pay, and we expect it to be online before the end of the first quarter of 2011. The second well is the Main Pass 180 A-2 well in which we own a 100% working interest. The well reached a total vertical depth of 13,950 feet and found approximately 91 feet of high quality gas sands in three separate zones.
Reserves: At December 31, 2010, total proved reserves were 485.4 Bcfe, compared to proved reserves of 371.0 Bcfe at the end of 2009. The 31% increase in proved reserves is primarily due to the newly acquired properties from Shell and Total, success with the drill bit and positive revisions, which are partially offset by production. Year-end 2010 proved reserves are comprised of 53% natural gas and 47% oil and natural gas liquids based on a ratio of six Mcf to one barrel equivalent. In accordance with guidelines established by the SEC, our proved reserves as of December 31, 2010 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 2010 through December 2010. The present value of our total proved reserves only, discounted at 10% (referred to as "PV-10"*) was $1.9 billion at December 31, 2010 excluding the effect of estimated asset retirement obligations. PV-10, including estimated asset retirement obligations, was $1.5 billion. This is based on average prices of $4.38 per Mcf for natural gas and $75.96 per Bbl for oil and natural gas liquids, adjusted 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 is defined in the "Non-GAAP Financial Information" later in this press release.
The Company's proved reserves are summarized in the table below:
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