HOUSTON, Aug. 1, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its second quarter 2018 operational and financial results and third quarter and full year 2018 production and expense guidance. Some of the key highlights for the second quarter included:

• Mid-Year 2018 SEC proved reserves were 78.0 million Boe, up 5% from year-end 2017 SEC proved reserves, primarily due to upward revisions of previous estimates of 12.7 million Boe. The increase in proved reserves was more than sufficient to replace production and a conveyance of proved undeveloped reserves.
• The present value of our reported SEC proved reserves, discounted at 10% ("PV-10"), was $1.3 billion, a 30% increase from year-end 2017, primarily due to upward revisions of previous estimates and higher average prices.
• Production for the second quarter of 2018 averaged 37,571 barrels of oil equivalent ("Boe") per day (or 3.4 million Boe for the quarter), 60.1% of which was oil and natural gas liquids ("NGLs"). Production was impacted by well maintenance, weather, pipeline outages and platform maintenance that collectively resulted in deferred production of approximately 4,600 Boe per day. Our second quarter production was 2.7% higher than first quarter of 2018.
• Revenues for the second quarter of 2018 were $149.6 million, up $26.3 million, or 21.3% compared to the second quarter of 2017. Oil and NGLs sales made up 83.8% of revenues, compared to 75.1% in the second quarter of 2017. Our realized crude oil price was $67.09 per barrel, up 50.6% from second quarter 2017.
• Operating income for the second quarter of 2018 was $48.5 million, an increase of 47.4% or $15.6 million, over the second quarter of 2017.
• Net income for the second quarter of 2018 was $36.1 million, or $0.25 per share compared to net income of $33.3 million, or $0.23 per share in the second quarter of 2017. Net income for the second quarter of 2018 included $0.1 million of income tax expense, whereas net income for the second quarter of 2017 included an income tax benefit of $9.0 million. Excluding special items, adjusted net income for the second quarter of 2018 was $41.9 million and earnings were $0.29 per share.
• Cash flow from operating activities for the first six months of 2018 was $115.2 million, increasing over 75% from the first six months of 2017. Adjusted EBITDA for the second quarter of 2018 was $93.3 million, up $20.7 million, or 28.5% compared to the second quarter of 2017. Our Adjusted EBITDA margin was 62% for the second quarter of 2018, up from 59% in second quarter of 2017. For the first six months of 2018 our Adjusted EBITDA was $170.5 million, up $32.1 million or 23.2% over the same period in 2017. (See definitions and reconciliations of non-GAAP measures to GAAP measures at the end of this news release.)
• Closed on the previously announced joint venture drilling program with private investors ("the JV Drilling Program"), in June 2018 through Monza Energy LLC. In total, the JV Drilling Program raised $361.4 million of equity from outside investors and W&T for the development of 14 pre-identified projects in the GOM, four of which are underway, or on production.
• Acquired a 9.375% non-operated working interest in the Heidelberg Field, as previously announced.

Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "We had an excellent second quarter, with a high level of cash flow generation and continued drilling success. During the quarter our production volumes, which came in at the mid-range of our guidance, benefited from a 39.5% increase in our realized sales price, while our lease operating costs were significantly lower than anticipated, driving a 47.4% increase in operating income compared to the same period last year.

"Our Mahogany and Virgo Fields continue to add substantial value with additional successful wells in both fields this year. Earlier in the year we completed and began producing the A-17 well at Mahogany and just recently completed and brought on line the A-5 sidetrack well that tested at about 2,700 Boe per day gross. At our Virgo Field we completed and brought on line the A-10 ST well and are currently drilling the A-12 well. At our Ewing Bank 910 field, we are currently drilling the ST320 A-2 well and expect to reach total depth this quarter and if successful, commence completion operations shortly thereafter. Each of these fields has existing infrastructure that allow for quick cash flow generation, which substantially shortens our payback and accordingly increases our rates of return.

"Funding for the JV Drilling Program was closed in June which raised $361.4 million from outside investors and W&T, which is expected to cover the cost to drill and complete 14 identified projects. The program is off to an excellent start with three successful wells drilled so far and two wells currently underway. The JV Drilling Program is helping us maximize our liquidity, while increasing our cash flow. Our capital expenditures for the first six months of 2018 were $31.8 million and our Adjusted EBITDA was $170.5 million. The JV Drilling Program was a key aspect of our strategy to increase our free cash flow, strengthen our balance sheet and put ourselves in an excellent position to manage our debt obligations as well as end the year with a much improved financial position," concluded Mr. Krohn.

Production, Prices and Revenues: Production for the second quarter of 2018 was 3.4 million Boe, compared to the second quarter 2017 of 3.9 million Boe. Second quarter 2018 production was comprised of 1.7 million barrels of oil, 0.3 million barrels of NGLs and 8.2 billion cubic feet ("Bcf") of natural gas. Oil and NGLs production comprised 60.1% of total production in the second quarter of 2018 compared to 58.0% of total production in the second quarter of 2017.

Production for the second quarter of 2018 was below the 2017 level partially due to natural production decline, as well as, well maintenance, weather, pipeline outages, and platform maintenance that collectively resulted in deferred production of approximately 4,600 Boe per day, compared to 3,400 Boe per day in the second quarter of 2017.

For the second quarter of 2018, production increases came from our newly acquired 9.375% non-operated working interest in the Heidelberg field, our Ship Shoal 300 field (with the completion of the SS300 B-5ST in November 2017), our Mahogany field and our Virgo field. These gains were offset by production decreases primarily due to natural production declines and production deferrals discussed above.

For the second quarter of 2018, our realized crude oil sales price was $67.09 per barrel (a 50.6% increase over the second quarter of 2017), our realized NGL sales price was $27.61 per barrel and our realized natural gas sales price was $2.81 per Mcf. Our combined average realized sales price was $43.38 per Boe, which represents a 39.5% increase over the $31.10 per Boe sales price that we realized in the second quarter of 2017.

Revenues for the second quarter of 2018 increased 21.3% to $149.6 million compared to $123.3 million in the second quarter of 2017. The increase was due to a 39.5% increase in our realized commodity sales price per Boe, partially offset by a 12.8% decrease in production volumes. We sold 37,571 Boe per day at an average realized sales price of $43.38 per Boe compared to 43,084 Boe per day at an average realized sales price of $31.10 per Boe in the second quarter of 2017.

Lease Operating Expenses: Lease operating expense ("LOE"), which includes base lease operating expenses, insurance premiums, workovers and facilities maintenance, was $35.6 million in the second quarter of 2018 compared to $31.5 million in the second quarter of 2017. On a component basis, base lease operating expenses were $29.9 million, insurance premiums were $2.8 million, workovers were $1.6 million and facilities maintenance was $1.3 million. Base LOE was up $3.1 million from the second quarter of 2017, primarily due to the addition of the Heidelberg field, lower production handling fees at one of our properties and an increase in cost at some of our non-operated properties. Facilities maintenance increased $0.7 million primarily for pipeline and compressor repairs. Insurance premiums were up $0.5 million due to better coverage on our energy package while workover expenses decreased $0.2 million.

Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for asset retirement obligations ("ARO"), was $11.63 per Boe for the second quarter of 2018 compared to $10.29 per Boe for the second quarter of 2017. On a nominal basis, DD&A was $39.8 million for the second quarter of 2018, which was down from $40.4 million in the second quarter of 2017 due to lower production volumes.

General and Administrative Expenses ("G&A"): G&A was $14.2 million for the second quarter of 2018, decreasing 13.7% compared to $16.5 million in the second quarter of 2017. The decrease was primarily due to declines in share-based compensation and legal costs.

Derivative (gain) loss: In the second quarter of 2018 we recorded a loss of $6.2 million on our outstanding crude oil commodity derivative contracts, $5.1 million of which was unrealized. This compared to a gain of $3.7 million in the second quarter of 2017 on the then outstanding crude oil derivative contracts that expired at the end of 2017. Approximately $2.2 million of that gain was unrealized at the end of the second quarter of 2017. A list of our currently outstanding derivative positions may be found on our website at www.wtoffshore.com in the investor relations section under "other reports" tab.

Interest expense: Interest expense was $12.1 million in the second quarter of 2018, compared to $11.4 million in the second quarter of 2017. The increase represents an interest accrual on a potential settlement of a royalty claim.

Income Tax: We recorded income tax expense of $0.1 million in the second quarter of 2018 on pre-tax income of $36.2 million, compared to an income tax benefit of $9.0 million on pre-tax income of $24.3 million in the second quarter of 2017. Our current full-year forecast for 2018 has a net operating loss for tax purposes; therefore, no current tax expense was recorded and any deferred tax expense was offset dollar for dollar with the valuation allowance. Minor adjustments were recorded to tax expense for an uncertain tax position.

The balance sheet at June 30, 2018, reflects current income tax receivables of $65.2 million, which relates to our net operating loss claims for plug and abandonment work that qualifies as a specified liability loss for tax purposes, allowing for net operating losses to be carried back to prior years.

Net Income & Earnings Per Share: We reported net income for the second quarter of 2018 of $36.1 million, or $0.25 per common share. Excluding special items, our adjusted net income was $41.9 million, or $0.29 per share. For the second quarter of 2017, we reported net income of $33.3 million, or $0.23 per common share; excluding special items, adjusted net income for the second quarter of 2017 was $31.1 million, or $0.22 per share. (See the "Reconciliation of Net Income to Net Income Excluding Special Items" and related earnings per share, excluding special items in the table under "Non-GAAP Information" at the end of this news release for a description of the special items.)

Cash Flow and Adjusted EBITDA: Net cash provided by operating activities for the six months ended June 30, 2018, was $115.2 million compared to $65.6 million for the six months ended June 30, 2017. The increase is primarily due to higher realized prices for crude oil and NGLs and lower spending on plug and abandonment activities.

Cash flows from operating activities before changes in working capital were $150.4 million in the first half of 2018, compared to $129.2 million for the same period in 2017 due to substantially better operating results.

Adjusted EBITDA for the second quarter of 2018 was $93.3 million and our Adjusted EBITDA margin was 62% compared to Adjusted EBITDA of $72.6 million and an Adjusted EBITDA margin of 59% for the second quarter of 2017. Adjusted EBITDA and Adjusted EBITDA margin are non-GAAP measures and are defined in the "Non-GAAP Information" section at the end of this news release.

Liquidity: At June 30, 2018, our total liquidity was $269.7 million, consisting of an unrestricted cash balance of $129.4 million and $140.3 million of availability under our $150 million revolving bank credit facility. By July 30, 2018, our cash balance had grown to $190.8 million and our total liquidity was $331.1 million.

Capital Expenditures: Our capital expenditures for oil and gas properties on an accrual basis for the first six months of 2018 were $31.8 million, compared to $43.8 million for the 2017 period. The 2018 period reflects a net reimbursement from Monza Energy LLC of $21.1 million for wells drilled or being drilled and that were contributed by W&T to Monza. During the six months ended June 30, 2018, we completed the A-17 well at Mahogany, which began producing during March 2018, and we completed the Viosca Knoll 823 ("Virgo") A-10 ST well, which began production during April 2018. The Virgo A-10 ST well is in the JV Drilling Program. At June 30, 2018 there were three wells being drilled including the A-5 ST at Mahogany, the A-12 well at Virgo and the ST 320 A-2 well at our Ewing Bank 910 field. Each of the wells in progress at the end of the quarter is part of the JV Drilling Program. During the six months ended June 30, 2017, we completed three wells. We did not have any dry holes in either period.

Mid-Year 2018 Proved Reserves: SEC proved reserves as of June 30, 2018 totaled 78.0 million Boe, an increase of 5% from year-end 2017 proved reserves. The mid-year 2018 reserves, which were 80% proved developed and proved developed non-producing, were 58% liquids. The present value of our SEC proved reserves, discounted at 10% ("PV-10"), was $1.3 billion, a 30% increase from year-end 2017, primarily due to upward revisions of previous estimates and higher average prices. The SEC PV-10 is based on an average crude oil price of $57.67 per barrel and average natural gas price of $2.92 per Mcf, both before adjustment for quality, transportation fees, energy content, and regional price differentials.

OPERATIONS UPDATE

We are currently operating or participating in three active drilling programs in the Gulf of Mexico, as described below.

Ship Shoal 349 "Mahogany" (operated, shelf, in the JV Drilling Program): The SS349 A-5ST was completed in July and began producing. The well targeted the 'Q' and 'P' sands and is currently producing around 2,000 Boe per day gross. This is the only well in the Mahogany field that is part of the JV Drilling Program.

Ship Shoal 349 "Mahogany" (operated, shelf, 100% working interest): Once the rig at Mahogany completed the A-5 ST well the rig skid over to begin drilling the A-19 well. The well is targeting a number of field pay sands in our Mahogany field.

Viosca Knoll 823 "Virgo" (operated, shelf, in JV Drilling Program): The A-10 ST well was completed and brought on line in April 2018. The platform rig was skid and commenced drilling the A-12 well (that is in block VK779). This well is structurally higher and up dip to another well that has logged pay in a principal target sand. Following the A-12 well, the rig is expected to commence drilling the A-13 well.

Ewing Bank 910 Field Area (deepwater, in JV Drilling Program, non-operated well): In mid-May, a rig spud and is currently drilling the ST 320 A-2 well from the South Timbalier 311 Platform that is all part of the Ewing Bank 910 field. Following the A-2 well operations, the rig is then expected to drill the ST320 A-3 well. We believe both of these wells are low-risk exploration opportunities with multiple stacked pay sands. Assuming success, these wells are expected to be brought on line quickly via existing infrastructure and pipelines.

Well Recompletions and Workovers: During the second quarter of 2018 we performed one recompletion that added approximately 261 Boe per day of initial production and six workovers that added approximately 2,743 Boe per day of initial production.

Third Quarter and Full Year 2018 Production and Expense Guidance

Our guidance for the third quarter and full year 2018 in the table below represents the Company's best estimate of the range of likely future results. Guidance could be affected by the factors described below in "Forward-Looking Statements".

Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, August 2, 2018, at 10:00 a.m. Eastern Time (9:00 a.m. Central Time). To participate, dial 412-902-0030 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 after the call until August 9, 2018, and may be accessed by calling 201-612-7415 and using the passcode 13681585#.

About W&T Offshore

W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico and has grown through acquisitions, exploration and development. The Company currently has working interests in 48 producing fields in federal and state waters and has under lease approximately 650,000 gross acres, including approximately 440,000 gross acres on the Gulf of Mexico Shelf and approximately 210,000 gross acres in the deepwater. A majority of the Company's daily production is derived from wells it operates. For more information on W&T Offshore, please visit the Company's website 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, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. 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 W&T Offshore's Annual Report on Form 10-K for the year ended December 31, 2017 and subsequent Form 10-Q reports found at www.sec.gov or at our website at www.wtoffshore.com under the Investor Relations section. Investors are urged to consider closely the disclosures and risk factors in these reports.

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 "Net Income Excluding Special Items," "EBITDA" and "Adjusted EBITDA." Our management uses these non-GAAP financial 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 Net Income Excluding Special Items

"Net Income Excluding Special Items" does not include the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, gain on exchange of debt, lawsuits and settlements, and penalties, litigation and related interest and associated income tax adjustments. Net Income 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.

W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information

Reconciliation of Net Income to Adjusted EBITDA

We define EBITDA as net income plus income tax expense (benefit), net interest expense, and depreciation, depletion, amortization. Adjusted EBITDA excludes the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, gain on exchange of debt, lawsuits and settlements, and civil penalties and other litigation. We believe the presentation of EBITDA and Adjusted EBITDA provides useful information regarding our ability to service debt and to fund capital expenditures. We believe this presentation 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 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. Adjusted EBITDA margin represents the ratio of Adjusted EBITDA to total revenues.

The following table presents a reconciliation of our net income to EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.