COST: 200 $MM
VOLUMES: 19.8 MBOE/d
COST: 31.1 $MM
VOLUMES: 3 MBOE/d
DENVER, July 10, 2019 /PRNewswire/ -- One of the largest independent upstream oil and gas-focused investor conferences—The Oil & Gas Conference®—will take place Aug. 11-14, 2019, at the Denver Downtown Westin hotel.
The event is EnerCom's 24th annual Denver investment conference. At this year's conference, c-level leadership of leading oil and gas companies will present their plans for drilling and completing wells, discuss well results and capital efficiency, and estimate capital expenditures and production for the balance of 2019 and into 2020.
For the buyside investment community, the EnerCom conference provides top level access to oil and gas company c-suites. The four-day conference allows institutional investors to set one-on-one meetings with company management teams. Meetings are limited to buyside principals, portfolio managers, CIOs and securities analysts. Individual company meeting requests must be made in advance as part of the online conference registration process.
The publicly traded companies that make up the exclusive group of energy producers and oilfield service and royalty companies at the EnerCom conference represent a combined total of:
By way of comparison to EnerCom's 2017 conference, total market cap for the 2019 public company group is 34% higher than combined market cap of the 2017 presenters as of August 2017; enterprise value for the 2019 presenting companies is 26% higher than it was for the 2017 public companies; and oil equivalent production for the 2019 presenting companies is 47% higher than combined production for the 2017 presenting upstream companies.
Presenting companies represent oil and gas operations in all of North America's shale basins, Latin America's conventional oil plays, the Gulf of Mexico and other international oil and gas plays. The EnerCom conference is a convenient way for portfolio managers and analysts to see approximately 85+ oil and gas companies together at a single venue where informal networking and one-on-one access to company management is part of the conference experience.
A sample of the companies that are scheduled to present Aug. 12-14, 2019 at the 2019 EnerCom conference include:
Day Three Presenting Companies
Presenting companies for Day Three of The Oil & Gas Conference® include but are not limited to:
(NYSE: CHAP) - Chaparral Energy, Inc.
(NASDAQ: ROSE) - Rosehill Resources Inc.
Privately held - Ameredev II
(NYSE: FTK) - Flotek Industries, Inc
(NYSE: WFC) - Wells Fargo & Company
(NYSE: E) – Keynote Lunch: Eni, SpA
(NASDAQ: PVAC) - Penn Virginia Corporation
(OTCMKTS: BNKPF) - BNK Petroleum, Inc.
(TSE: JOY) - Journey Energy Inc.
(NYSE AMERICAN: NES) - Nuverra Environmental Solutions
The complete daily schedule of presenters is posted on the website (presenters, days, times are subject to change). The conference investor presentations begin at 7:30 a.m. and run through 4:30 p.m.
Online Registration is Open for EnerCom's 24TH Annual The Oil & Gas Conference®: Buyside investors and oil and gas company professionals may register for the event through the conference website registration page.
The EnerCom conference forum fosters healthy dialogue and informal networking opportunities for attendees at several sponsored events the week of the conference.
Public and Private Company Presenters: The 2019 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations around the world including the U.S. shale basins, the Gulf of Mexico and Canada. A work-in-progress list of the 2019 presenting companies will be updated on the conference website.
How to Hear the Luncheon Speakers: Completing online registration well in advance of The Oil & Gas Conference® will provide your best chance to gain insight from Occidental Petroleum SVP and chief financial officer Cedric Burgher, Continental Resources Chairman and CEO Harold Hamm, and global supermajor Eni, SpA VP of North America Investor Relations Andrew Lees.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, family offices, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2018, EnerCom arranged and managed more than 2,000 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies may register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; and Drillinginfo. Sponsors of The Oil & Gas Conference® 24 include CIBC; Credit Agricole CIB; McGriff, Seibels & Williams; Haynes and Boone; Moss Adams; PNC; Preng & Associates; Bank of America Merrill Lynch; DNB Bank ASA; Holland & Hart; MUFG; Petrie Partners; SMBC; and Wells Fargo.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized management consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor relations, media relations, external communications and visual communications design.
EnerCom offers investor relations consulting and it produces and publishes numerous data products and external communications tools for public energy companies and oil and gas investors including:
Headquartered in Denver, with senior consultants in Dallas, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries. EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 11-14, 2019
EnerCom Dallas – March 4-5, 2020
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
Drillinginfo
Drillinginfo delivers business-critical insights to the energy, power, and commodities markets. Its state-of-the-art SaaS platform offers sophisticated technology, powerful analytics, and industry-leading data. Drillinginfo's solutions deliver value across upstream, midstream and downstream markets, empowering exploration and production (E&P), oilfield services, midstream, utilities, trading and risk, and capital markets companies to be more collaborative, efficient, and competitive. Drillinginfo delivers actionable intelligence over mobile, web, and desktop to analyze and reduce risk, conduct competitive benchmarking, and uncover market insights. Drillinginfo serves over 5,000 companies globally from its Austin, Texas headquarters and has more than 1,000 employees.
For more information visit drillinginfo.com
CIBC
CIBC is a leading Canadian-based global financial institution with a reputation as a strong, reliable banking partner focused on delivering customized products and services built on innovative thinking and leading technology.
Through our major business units – Canadian Personal & Business Banking, Canadian Commercial Banking & Wealth Management, U.S. Commercial Banking & Wealth Management and Capital Markets – our more than 45,000 employees provide a full range of financial products and services to 10 million clients around the world.
With offices throughout North America and other major financial centers, we are widely recognized as a strong global financial institution with more than $634 billion in assets and a market capitalization of $50 billion. We are rated A+ by Standard & Poor's, Aa2 by Moody's Investor Service and AA- by Fitch Ratings.
Our dedicated industry specialists based in Houston, New York, Calgary, London, Hong Kong, Beijing, Tokyo, Singapore and Sydney draw on the breadth of our capabilities to support firms across the entire energy value chain. From credit commitments, A&D advisory, M&A, and capital markets, we help our clients achieve their objectives and unlock value across a range of market conditions.
Visit www.cibccm.com/energy to learn more about CIBC Capital Markets and our energy capabilities.
Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
McGriff, Seibels & Williams
As one of the most progressive insurance brokerage firms in the United States, McGriff, Seibels & Williams leads the way with innovative programs to protect our clients' financial interests.
Our experienced professionals work with some of the world's largest corporations to design state-of-the-art solutions for a full range of needs "…from property and casualty exposures…to employee benefits, life and pension plans…to financial services and surety products…to specialty insurance programs."
Our philosophy of personal service and attention to individual needs puts the client at the top of our organizational chart. We work to make each relationship a long-term partnership that continues to grow in value.
For more information please visit mcgriff.com.
Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group.
With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom. PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
Holland & Hart
Holland & Hart's oil and gas clients include the major, large independent producers and small to medium sized independents.
The Mountain West is one of the nation's leading oil and gas producing regions, and we are the only law firm with established oil and gas lawyers in every state in the region. We provide clients broad-based, in-depth industry knowledge and legal capabilities by local practitioners who have long-standing professional relationships with decision makers in each of the Mountain West states.
We assist clients at every stage of the oil and gas business, from upstream activities including exploration, production, secondary and tertiary recovery, to midstream gathering and processing activities; and to downstream elements including refining, pipelines, local distribution, marketing, and Federal and State utility regulation. Within each segment of the oil and gas business, Holland & Hart's regional team has experience providing representation every step of the way.
For details, please contact Lisa Adelberg in the Denver office: (303) 295-8148.
MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
Petrie Partners
Petrie Partners, LLC is a boutique investment banking firm offering financial advisory services to the oil and gas industry. We provide specialized advice on mergers, divestitures and acquisitions and private placements.
For more information please refer to petrie.com.
SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
Wells Fargo & Company
Wells Fargo & Company (NYSE: WFC) is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
View original content:http://www.prnewswire.com/news-releases/public-oil--gas-companies-scheduled-for-the-oil--gas-conference-represent-158-billion-in-energy-industry-market-capitalization-300882258.html
SOURCE EnerCom, Inc.
DENVER, June 12, 2019 /PRNewswire/ -- EnerCom has released the presentation schedule for the oil and gas companies presenting at its 24th annual The Oil & Gas Conference® on Aug. 11-14, 2019, in Denver, Colorado.
Day One Presenting Companies at the 2019 EnerCom Conference
Aug. 12, 2019, the first day of the EnerCom conference presentation schedule, features a large, established group of operators working across North America's shale basins and internationally, including:
The conference investor presentations begin at 7:30 a.m. and run through 4:30 p.m. on Monday, Aug. 12.
Expert Speakers: Global energy industry leaders, economists, market strategists, government officials, energy finance professionals and other energy experts will provide their insights on global commodities markets, energy exports, frac sand supply and logistics, and capital sources for energy development.
EnerCom is pleased to include Credit Agricole CIB's Chief Economist for the United States Michael Carey as a guest expert speaker at 11:30 a.m. on Monday, Aug. 12. Carey will provide his insight on energy markets, capital markets and market conditions going forward.
Monday's luncheon keynote address on Aug. 12, 2019 will be provided by Cedric Burgher, Occidental Petroleum (NYSE: OXY) CFO.
Online Registration is Open for EnerCom's 24TH Annual The Oil & Gas Conference®: Buyside investors and oil and gas company professionals may register for the event through the conference website registration page.
Conference Details: The Oil & Gas Conference® 24 offers investment professionals the opportunity to listen to senior management teams in the oil and gas industry present operational and financial strategies and to gain exposure to important energy topics affecting the global oil and gas industry.
The EnerCom conference forum fosters healthy dialogue and informal networking opportunities for attendees at several sponsored events the week of the conference.
Public and Private Company Presenters: The 2019 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations around the world including the U.S. shale basins, the Gulf of Mexico and Canada. A work-in-progress list of the 2019 presenting companies will be updated on the conference website. The daily schedule of presenters is also posted on the website (presenters, days, times are subject to change).
How to Hear the Luncheon Speakers: Completing online registration well in advance of The Oil & Gas Conference® will provide your best chance to gain insight from Occidental Petroleum SVP and chief financial officer Cedric Burgher, Continental Resources Chairman and CEO Harold Hamm, and global supermajor Eni, SpA VP of North America Investor Relations Andrew Lees.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, family offices, energy research analysts, retail brokers, trust officers, high net worth investors, investment bankers and energy industry professionals gather in Denver for the conference.
One-on-One Meetings: EnerCom works in advance with presenting company management teams to arrange one-on-one meetings with the attending institutional investors and research analysts at the conference venue. In 2018, EnerCom arranged and managed more than 2,000 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies may register for the event through the conference website.
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; and Drillinginfo. Sponsors of The Oil & Gas Conference® 24 include CIBC; Credit Agricole CIB; McGriff, Seibels & Williams; Haynes and Boone; Moss Adams; PNC; Preng & Associates; Bank of America Merrill Lynch; DNB Bank ASA; Holland & Hart; MUFG; Petrie Partners; SMBC; and Wells Fargo.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized management consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor relations, media relations, external communications and visual communications design.
EnerCom produces and publishes numerous data products and external communications tools for public energy companies and oil and gas investors including:
Headquartered in Denver, with senior consultants in Dallas, EnerCom uses the team approach for delivering its wide range of services to public and private companies, large and small, operating in the global exploration and production, OilService, capital markets, and associated advanced-technology industries. EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
EnerCom's upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 11-14, 2019
EnerCom Dallas – Q1 - 2020
For more information about EnerCom and its services, please visit http://www.enercominc.com/ or call +1 303-296-8834 to speak with the management team or one of our consultants.
About Netherland, Sewell & Associates, Inc.
Netherland, Sewell & Associates, Inc. (NSAI) was founded in 1961 to provide the highest quality engineering and geological consulting to the petroleum industry. Today they are recognized as the worldwide leader of petroleum property analysis to industry and financial organizations and government agencies. With offices in Dallas and Houston, NSAI provides a complete range of geological, geophysical, petrophysical, and engineering services and has the technical experience and ability to perform these services in any of the onshore and offshore oil and gas producing areas of the world. They provide reserves reports and audits, acquisition and divestiture evaluations, simulation studies, exploration resources assessments, equity determinations, and management and advisory services. For a complete list of services or to learn more about Netherland, Sewell & Associates, Inc. please visit www.netherlandsewell.com.
For more information about NSAI, call C.H. (Scott) Rees, Chief Executive Officer, at 214-969-5401 or send an email to info@nsai-petro.com.
About Drillinginfo
Drillinginfo delivers business-critical insights to the energy, power, and commodities markets. Its state-of-the-art SaaS platform offers sophisticated technology, powerful analytics, and industry-leading data. Drillinginfo's solutions deliver value across upstream, midstream and downstream markets, empowering exploration and production (E&P), oilfield services, midstream, utilities, trading and risk, and capital markets companies to be more collaborative, efficient, and competitive. Drillinginfo delivers actionable intelligence over mobile, web, and desktop to analyze and reduce risk, conduct competitive benchmarking, and uncover market insights. Drillinginfo serves over 5,000 companies globally from its Austin, Texas headquarters and has more than 1,000 employees.
For more information visit drillinginfo.com
About CIBC
CIBC is a leading Canadian-based global financial institution with a reputation as a strong, reliable banking partner focused on delivering customized products and services built on innovative thinking and leading technology.
Through our major business units – Canadian Personal & Business Banking, Canadian Commercial Banking & Wealth Management, U.S. Commercial Banking & Wealth Management and Capital Markets – our more than 45,000 employees provide a full range of financial products and services to 10 million clients around the world.
With offices throughout North America and other major financial centers, we are widely recognized as a strong global financial institution with more than $634 billion in assets and a market capitalization of $50 billion. We are rated A+ by Standard & Poor's, Aa2 by Moody's Investor Service and AA- by Fitch Ratings.
Our dedicated industry specialists based in Houston, New York, Calgary, London, Hong Kong, Beijing, Tokyo, Singapore and Sydney draw on the breadth of our capabilities to support firms across the entire energy value chain. From credit commitments, A&D advisory, M&A, and capital markets, we help our clients achieve their objectives and unlock value across a range of market conditions.
Visit www.cibccm.com/energy to learn more about CIBC Capital Markets and our energy capabilities.
About Crédit Agricole Corporate and Investment Bank
Crédit Agricole Corporate and Investment Bank is the corporate and investment banking arm of the Crédit Agricole Group, the world's eighth largest bank by total assets (The Banker, July 2014). Crédit Agricole CIB offers its clients a comprehensive range of products and services in capital markets, brokerage, investment banking, structured finance, corporate banking, and international private banking.
With headquarters in New York City, and U.S. offices in Houston and Chicago, Credit Agricole CIB Americas offers its corporate and institutional clients financial products and services and made-to-order structuring, origination and distribution, through both its banking unit Credit Agricole CIB, and the full-service broker-dealer Credit Agricole Securities (USA) Inc., which is a member of the NYSE and NASD. Credit Agricole CIB is also present in Montreal, Canada, and in Latin America with offices in Argentina, Brazil, and Mexico.
The Energy Industry represents the single largest concentration of industry exposure at Credit Agricole Corporate and Investment Bank, whose specialty focus dates back over 100 years. Our Energy practice for North America, located in Houston, focuses on all segments of the business and covers it on a truly global basis.
For more information, visit www.ca-cib.com.
McGriff, Seibels & Williams
As one of the most progressive insurance brokerage firms in the United States, McGriff, Seibels & Williams leads the way with innovative programs to protect our clients' financial interests. Our experienced professionals work with some of the world's largest corporations to design state-of-the-art solutions for a full range of needs "…from property and casualty exposures…to employee benefits, life and pension plans…to financial services and surety products…to specialty insurance programs."
Our philosophy of personal service and attention to individual needs puts the client at the top of our organizational chart. We work to make each relationship a long-term partnership that continues to grow in value.
For more information please visit mcgriff.com.
About Haynes and Boone
Haynes and Boone, LLP is an energy-focused corporate law firm, providing a full spectrum of legal services to our clients across the oil and gas industry, including the upstream, midstream, and downstream sectors. We serve energy clients from our offices in Texas, Colorado, New York, California, Washington, D.C., London, Mexico City and Shanghai. We work as a team representing U.S. and foreign public and private companies engaged in the dynamic day-to-day work of finding and extracting oil and gas, and the banks, investment funds and other investors that support them.
Our team of more than 100 energy lawyers and landmen understands the U.S. and international physical and financial energy markets, and the firm has been helping operators and lenders complete some of the largest financings and M&A transactions in recent years. With more than 600 attorneys, Haynes and Boone is ranked among the largest law firms in the nation by The National Law Journal, and our energy lawyers have been ranked by publications such as Best Lawyers in America, Chambers and Partners and Who's Who in Energy.
For more info, please visit www.haynesboone.com.
About Moss Adams LLP
For more than 30 years, Hein & Associates has been recognized throughout the industry as a leading oil and gas accounting and advisory firm. In late 2017, Hein combined with Moss Adams LLP, one of the largest accounting, consulting and wealth management firms in the nation, creating a $600 million middle-market accounting/tax/audit leader in the western U.S. with a strong oil & gas practice group. With more than 2,900 professionals and staff across more than 25 locations in the West and beyond, Moss Adams works with many of the world's most innovative companies and leaders. Our strength in the middle market enables us to advise clients at all intervals of development—from start-up, to rapid growth and expansion, to transition. Today, we help over 2,300 companies doing business in more than 100 countries and territories.
For more information, please contact Joe Blice, Partner, National Practice Leader, Oil & Gas, CPA joe.blice@mossadams.com, (972) 687-7818.
Moss Adams LLP provides details at https://www.mossadams.com/home .
About PNC Financial Services Group
PNC is one of the largest, best-regarded and best-capitalized financial services companies in the country, with approximately $325 billion in assets and offices in 33 states, Canada and the United Kingdom.
PNC's Energy Group, headed by Tom Byargeon, is a significant capital and service provider to energy companies, with approximately $6.5 billion in commitments to the industry. The Energy office in Houston houses a team with extensive experience and deep relationships across the entire energy supply chain. This group also offers strategic corporate finance advice and delivers PNC's comprehensive set of solutions and capabilities, including commodity and interest rate hedging, debt capital markets, loan syndications, treasury management, asset securitization, equipment finance and institutional investments.
For more information, please contact Tom Byargeon at 713-353-8782 or tom.byargeon@pnc.com. You can also visit www.pnc.com.
About Preng & Associates
Preng & Associates, founded in 1980, is the only retainer-based, international executive search firm specializing solely in the energy industry. Its number one priority is to assist clients with their executive selection, organization development, and human resource needs by providing the highest quality service. Preng's record of accomplishment is directly attributable to their experienced staff, worldwide network of industry contacts, proven search methodology, and high standards of professionalism. Preng has conducted over 3000 searches for board, executive, management, and professional positions in its 35-year history and has the highest success and repeat client track record.
Preng's practice is based on the premise that the search process is most effective when conducted by professionals with significant search industry experience. The company has earned a reputation for combining professional search disciplines with an in-depth industry and market understanding and has succeeded in some of the industry's most challenging and high-profile searches. Preng's international reach allows it to effectively conduct global engagements; and as a member of the Association of Executive Search Consultants, Preng practices and promotes its high standards of conduct and professionalism.
For more information about Preng & Associates, contact Charles Carpenter, Partner at 713-243-2610 or ccarpenter@preng.com.
About Bank of America Merrill Lynch
Bank of America Merrill Lynch Oil and Gas Group
The Bank of America Merrill Lynch (BofAML) Oil and Gas practice is comprised of a global team of bankers dedicated to covering the energy industry, dating back to the 1920s when Texas predecessor banks pioneered reserve-based lending. The practice includes an experienced in-house Petroleum Engineering team with over 150 years of combined experience. With one of the only full-service financial energy platforms in the industry, the BofAML oil and gas team manages significant capital commitments in the energy sector with dedicated bankers based in Calgary, Denver, Dallas, Houston, London and New York.
The BofA Merrill Lynch Global Research platform offers clients access to information and actionable ideas on stocks, bonds, economics and investment strategies. With approximately 700 analysts in more than 20 countries, we offer our clients knowledge about economic and business developments that are having an impact on the markets, so that they can work with their financial advisors to make the most of opportunities. BofA Merrill Lynch Global Research was ranked No. 1 for the fourth consecutive year on the 2014 list of Top Global Research Firms, Institutional Investor.
About DNB ASA
DNB is Norway's largest financial services provider, with total assets approaching $400 billion. The bank has for years been a major provider of capital to the oil & gas industry, growing up literally side by side with the highly prolific fields developed in the Norwegian Sector of the North Sea. The Oslo Energy Office maintains a global financing strategy and serves this market through multiple offices around the world including Houston, London and Singapore.
Energy Americas, based in Houston, comprises approximately 20 seasoned energy finance professionals. Aside from facilitating the bank's global business strategies, the office concentrates primarily on serving middle market and larger customers in the four principal oil & gas sectors — upstream, midstream, downstream and service — as well as in Power and Renewables. The bank offers a variety of financial products, from traditional oil & gas reserve financing, to longer-term capital markets transactions and merger/acquisition advisory services through its broker-dealer arm, DNB Markets, Inc. Ancillary service capabilities include cash management/depository services, as well as commodity and interest rate hedging.
For information on DNB's energy services, please visit the DNB energy website.
About Holland & Hart
Holland & Hart's oil and gas clients include the major, large independent producers and small to medium sized independents.
The Mountain West is one of the nation's leading oil and gas producing regions, and we are the only law firm with established oil and gas lawyers in every state in the region. We provide clients broad-based, in-depth industry knowledge and legal capabilities by local practitioners who have long-standing professional relationships with decision makers in each of the Mountain West states.
We assist clients at every stage of the oil and gas business, from upstream activities including exploration, production, secondary and tertiary recovery, to midstream gathering and processing activities; and to downstream elements including refining, pipelines, local distribution, marketing, and Federal and State utility regulation. Within each segment of the oil and gas business, Holland & Hart's regional team has experience providing representation every step of the way.
For details, please contact Lisa Adelberg in the Denver office: (303) 295-8148.
About MUFG
Mitsubishi UFJ Financial Group (MUFG) has been a leading provider of banking services to the oil and gas industry in the Americas for more than 30 years, consistently ranking in the Top 10 Lead Arrangers and Top 10 Bond Arrangers in the Thomson Reuters Oil and Gas League Tables.
We support clients across the industry—from regional exploration and production to global diversified services companies—that benefit from our focused approach, strong execution, and customized services. Whether you are looking to expand existing reserves, make an acquisition, or streamline operations, we can support your growth with services, including: underwriting and syndications; U.S./Canadian cross-border funding; securities underwriting and placements; leasing and tax equity financing; and commodities, interest rate, and foreign exchange risk management.
For more information, visit: www.mufgamericas.com/oil-gas.
About Petrie Partners
Petrie Partners, LLC is a boutique investment banking firm offering financial advisory services to the oil and gas industry. We provide specialized advice on mergers, divestitures and acquisitions and private placements.
For more information please refer to petrie.com.
About SMBC
Sumitomo Mitsui Banking Corporation (SMBC) is a core member of Sumitomo Mitsui Financial Group (SMFG), a Tokyo-based bank holding company that is ranked among the largest 25 banks globally by assets under management.
SMBC Americas Division, with more than 2,500 employees, oversees operations in the U.S., Canada, Mexico, and South America. We work across SMFG to offer corporate and institutional clients sophisticated and comprehensive financial services around the globe.
SMBC's roots in Japan trace back more than 400 years to 1590. The Americas Division of SMBC has more than a century of experience in the United States, beginning when the San Francisco branch of Sumitomo Bank was established in 1919. Sumitomo Mitsui Financial Group (NYSE: SMFG) was listed on the New York Stock Exchange in 2010.
For more information please visit the corporate website: www.smbcgroup.com/americas/group-companies/
About Wells Fargo & Company
Wells Fargo & Company (NYSE: WFC) is a nationwide, diversified, community-based financial services company providing banking, insurance, investments, mortgage, and consumer and commercial finance through more than 8,700 locations, 12,500 ATMs, and the internet (wellsfargo.com) and mobile banking, and has offices in 36 countries to support customers who conduct business in the global economy.
The Energy Banking Group, headed by Bart Schouest, provides corporate banking products and services to the energy sector, including upstream, midstream, oilfield services, and diversified industries. With offices in Houston, Dallas, Denver, Calgary, and Aberdeen the group's success is driven by in-depth industry expertise and longstanding relationships with key industry participants. The group has over $45 billion of credit commitments to public and private companies across the upstream, midstream, downstream, services, and power and utilities sectors.
The Energy & Power Investment Banking Group, headed by James Kipp, provides strategic advisory and corporate finance expertise to energy and power clients, including upstream, midstream, oilfield services, downstream, coal and the power & utilities sectors. Areas of focus include equity, equity-linked and debt underwritings, private placements, syndications, and mergers and acquisitions. The Energy & Power Investment Banking Group has offices in Houston and Charlotte.
These teams work together to offer clients industry and product expertise, in addition to sharing their understanding of internal and external forces that drive both industry trends and financial markets. For additional information, contact us at 713-319-1350 or Energy@wellsfargo.com.
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SOURCE EnerCom, Inc.
HOUSTON, Dec. 3, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today announced that it has established additional commodity hedge positions.
The Company currently has the following commodity price hedges in place:
Crude Oil | ||||||||||
Quarter | Instrument | Average | Average | |||||||
Bbl/d | Strike Price | Floor | Ceiling | |||||||
4Q18 | WTI Collars | 2,000 | $55.00 | $72.75 | ||||||
WTI Collars | 2,000 | $60.00 | $69.50 | |||||||
WTI Swaps | 2,000 | $63.80 | $63.80 | $63.80 | ||||||
WTI Swaps | 3,370 | $60.92 | $60.92 | $60.92 | ||||||
WTI Puts (long) | 5,000 | $60.00 | $60.00 | |||||||
WTI Calls (long) | 3,370 | $61.00 | ||||||||
1Q19 | WTI Swaps | 10,000 | $60.92 | $60.92 | $60.92 | |||||
WTI Calls (long) | 10,000 | $61.00 | ||||||||
2Q19 | WTI Swaps | 10,000 | $60.92 | $60.92 | $60.92 | |||||
WTI Calls (long) | 10,000 | $61.00 | ||||||||
3Q19 | WTI Swaps | 10,000 | $60.92 | $60.92 | $60.92 | |||||
WTI Calls (long) | 10,000 | $61.00 | ||||||||
4Q19 | WTI Swaps | 10,000 | $60.92 | $60.92 | $60.92 | |||||
WTI Calls (long) | 10,000 | $61.00 | ||||||||
1Q20 | WTI Swaps | 10,000 | $60.92 | $60.92 | $60.92 | |||||
WTI Calls (long) | 10,000 | $61.00 | ||||||||
2Q20 | WTI Swaps | 6,703 | $60.92 | $60.92 | $60.92 | |||||
WTI Calls (long) | 6,703 | $61.00 |
Natural Gas | ||||||||
Quarter | Instrument | Average | Average | |||||
MMBtu/d | Floor | Ceiling | ||||||
4Q18 | NYMEX Collars | 32,152 | $2.55 | $3.76 | ||||
1Q19 | NYMEX Collars | 50,000 | $2.49 | $3.98 | ||||
2Q19 | NYMEX Collars | 50,000 | $2.49 | $3.98 |
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.
CONTACT: | Lisa Elliott | Janet Yang | |
Dennard Lascar Investor Relations | EVP & CFO | ||
713-529-6600 | 713-624-7326 |
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SOURCE W&T Offshore, Inc.
HOUSTON, Dec. 3, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that the Company will be participating in the Capital One Securities 13th Annual Energy Conference to be held in New Orleans on December 4-6, 2018.
Tracy Krohn, W&T Offshore's Chairman and CEO, is scheduled to make a presentation on Wednesday, December 5 at 10:30 a.m. Central Time. The presentation will provide an update on the Company's operations and will be broadcast over the Internet. The webcast link to the audio presentation and accompanying slides can be accessed live and for replay from the Company's website at www.wtoffshore.com by visiting the Event Calendar in the Investor Relations section.
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 approximately 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.
CONTACT: | Lisa Elliott | Janet Yang |
Dennard Lascar Investor Relations | EVP & CFO | |
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-to-present-at-the-capital-one-securities-13th-annual-energy-conference-300758535.html
SOURCE W&T Offshore, Inc.
HOUSTON, Nov. 6, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today announced certain executive management changes within the Company, effective immediately.
The Company announced the appointment of Janet Yang to Executive Vice President and Chief Financial Officer, following her appointment as acting Chief Financial Officer in August 2018. Ms. Yang will also assume the role of Principal Accounting Officer of the Company. Additionally, the Company announced the promotions of David M. Bump from Vice President to Executive Vice President, Drilling, Completions and Facilities and William J. Williford from Vice President to Executive Vice President and General Manager of Gulf of Mexico.
The Company also announced the departure of Thomas P. Murphy, Senior Vice President and Chief Operations Officer. Mr. Bump and Mr. Williford will be assuming the duties of Mr. Murphy.
Tracy Krohn, W&T Offshore's Chairman and CEO, stated, "These leadership changes support our vision for the next phase of our Company's success. Janet has demonstrated strong leadership in key strategic initiatives of the Company over the years, including our recently successful corporate debt reduction and refinancing as well as our drilling joint venture announced earlier this year. We appreciate her hard work and have complete confidence in her abilities to continue to effectively lead our financial operations. I am pleased to have her permanently move into the CFO role.
"We are also announcing the well-deserved promotions of David and William to Executive Vice President positions. They have both proven themselves to be highly effective and valuable leaders at W&T, and we are confident that they will continue to create value for the Company going forward. While we appreciate Tom's many contributions over the last several years and wish him well in his next endeavors, David and William are well prepared and have assumed his previous responsibilities to advance our growth."
Janet Yang joined W&T in 2008 and was appointed acting Chief Financial Officer in August 2018. Previously she was Finance Manager and in 2012 became Director, Strategic Planning & Analysis, a position she held until being appointed Vice President, Corporate & Business Development in 2017. Ms. Yang has over 16 years of finance, investment, capital markets and strategy experience in the energy industry. Prior to joining W&T, Ms. Yang held positions in research and investment analysis at BlackGold Capital Management, investment banking at Raymond James and energy trading at Allegheny Energy. Ms. Yang received a B.A. in Economics from Rice University and an M.B.A. with concentrations in Finance and Accounting from The University of Chicago Booth School of Business.
David M. Bump joined the company in April 2014 as Vice President, Drilling and Completions. Mr. Bump brings with him 25 years of domestic and international industry experience with both small and large independent operators. From 2011 to 2014, he worked for Anadarko Petroleum Corporation as the Drilling and Completions Manager overseeing the Mozambique operations. From 2006 through 2011, Mr. Bump served as Anadarko's Gulf of Mexico and International Deepwater Completions Manager. From 1997 until 2006, Mr. Bump held a variety of positions with Kerr-McGee Oil and Gas prior to the merger with Anadarko Petroleum Corporation. These positions included Gulf of Mexico/International Deepwater Completions Manager, Drilling Engineering Manager of China Operations, and Deepwater Drilling Engineer. Prior to 1997, he held various engineering positions at several small independent operators. Mr. Bump received Bachelor of Science Degree in Petroleum Engineering from Texas A&M University in 1989.
William J. Williford joined W&T in June 2006 and was appointed Vice President and General Manager Gulf of Mexico in 2018. Since 2006, he has served in various positions of increasing responsibility with the Company, including Reservoir Engineer, Exploration Project Manager, General Manager Deepwater Gulf of Mexico, and most recently, General Manager Gulf of Mexico Shelf and Deepwater. Mr. Williford has over 20 years of oil and gas technical experience with large independents in the Gulf of Mexico and Domestic Onshore. Prior to joining W&T, Mr. Williford held positions in reservoir, production, and operations at Kerr-McGee and Oryx Energy. Mr. Williford received a B.S. in Petroleum Engineering from Mississippi State University.
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.
CONTACT: | Lisa Elliott | Janet Yang |
Dennard Lascar Investor Relations | EVP & CFO | |
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-executive-management-changes-300745114.html
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 31, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its third quarter 2018 operational and financial results, fourth quarter and full year 2018 production and expense guidance. Some of the key highlights included:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "We are very pleased to have completely refinanced our debt, which included the successful and over-subscribed issuance of $625 million of new 9.75% senior second lien notes due November 2023 and a newly established revolving bank credit facility with a borrowing base of $250 million. We dramatically simplified our debt structure and reduced total debt principal outstanding from $903 million to $625 million plus $61 million currently drawn on the revolving bank credit facility. Our current liquidity is over $200 million, and with continued strong positive cash flow, we anticipate exiting 2018 with a much-improved balance sheet and the financial strength to pursue meaningful growth opportunities. W&T has a long history of completing acquisitions of producing assets in the Gulf of Mexico with upside potential and a demonstrated track record for significantly enhancing the value of those assets while boosting cash flow. We believe that market conditions in the Gulf are currently favorable for acquisitions and with our improved financial liquidity, we are very well positioned to benefit."
"Our continued drilling success and ability to put new projects online quickly in a positive commodity price environment has allowed us to significantly increase our cash flow. Since the end of the second quarter we drilled three more successful wells that are adding reserves and production. At the Mahogany field, our newly drilled A-19 well found high quality net pay in multiple sands. The first completion in the A-19 well will be in the 'T' sand. The 'T' sand was found up-dip from known oil which we believe further demonstrates that Mahogany is a world class asset. Additionally, we drilled another successful well at the Ewing Bank 910 field with an exploration discovery that also exceeded our pre-drill estimates. The ST 320 A-2 exploratory well logged approximately 163 vertical feet of pay sands. Both of these wells are currently being completed and are expected to be on production before year-end 2018. We will then continue our drilling programs in both of these fields. At our Virgo field we drilled the A-12 well, which found 60 feet of net vertical pay sands is in final stage of completion activity and is expected to be on production in November. The Virgo field rig is now drilling the A-13 well, which assuming success, would add production in early 2019. The A-12 and A-13 wells are part of the Monza Drilling Joint Venture," concluded Mr. Krohn.
Production, Prices and Revenues: Production for the third quarter of 2018 was 3.4 million Boe, flat with the third quarter of 2017. Third quarter 2018 production was comprised of 1.7 million barrels of oil, 0.3 million barrels of NGLs and 7.9 billion cubic feet ("Bcf") of natural gas. Oil and NGLs production comprised 61% of total production in the third quarter of 2018 compared to 60% of total production in the third quarter of 2017.
Production for the third quarter of 2018 exceeded the mid-point of the production guidance and was partially driven by less storm outage than was projected for the period.
Production increases over the prior year period primarily came from our newly acquired 9.375% non-operated working interest in the Heidelberg field and our Ship Shoal 300 field (with the completion of the SS 300 B-5ST in November 2017). These gains were offset by production decreases primarily due to natural production declines.
For the third quarter of 2018, our realized crude oil sales price was $69.57 per barrel (a 52% increase over the third quarter of 2017), our realized NGL sales price was $31.70 per barrel and our realized natural gas sales price was $2.85 per Mcf. Our combined average realized sales price was $45.32 per Boe, which represents a 40% increase over the $32.43 per Boe sales price that we realized in the third quarter of 2017.
Revenues for the third quarter of 2018 increased 39% to $153.5 million compared to $110.3 million in the third quarter of 2017 as a result of the 40% increase in our realized commodity sales price per Boe.
Lease Operating Expenses: Lease operating expense, which includes base lease operating expenses, insurance premiums, workovers and facilities maintenance, was $37.4 million in the third quarter of 2018 compared to $35.1 million in the third quarter of 2017. The increase was primarily due to higher workover expenses. On a component basis, base lease operating expenses were $29.6 million, insurance premiums were $3.1 million, workovers were $1.2 million and facilities maintenance was $3.5 million. Facilities maintenance tends to be seasonal and is typically lower during the winter months.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for asset retirement obligations, was $11.01 per Boe of production for the third quarter of 2018 compared to $10.88 per Boe for the third quarter of 2017.
General and Administrative Expenses ("G&A"): G&A was $16.0 million for the third quarter of 2018, an increase of 2% compared to $15.6 million in the third quarter of 2017. The increase was primarily due to an accrual for an executive's separation settlement, an increase in medical claims and the termination of an office lease.
Derivative (gain) loss: In the third quarter of 2018, we recorded a net gain of $0.3 million on our outstanding crude oil commodity derivative contracts. This compared to a net loss of $2.9 million in the third quarter of 2017 on the derivative contracts that expired at the end of 2017. A list of our derivative positions may be found on our website at www.wtoffshore.com in the investor relations section under "other reports" tab.
Income Tax: Income tax expense was $0.1 million in the third quarter of 2018 compared to income tax expense of $5.5 million in the third quarter of 2017. We are not forecasting any current income tax expense and our deferred expense is fully offset by a valuation allowance. Consequently, our effective tax rate is not meaningful. The balance sheet at September 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 specified liability losses for tax purposes, allowing net operating losses to be carried back to prior years.
Net Income & Earnings Per Share: Our net income for the third quarter of 2018 was $46.3 million, or $0.32 per common share. Excluding special items, our adjusted net income was $44.1 million, or $0.30 per share. For the third quarter of 2017, our net loss was $1.3 million, or $0.01 loss per share; excluding special items, adjusted net income for the third quarter of 2017 was $6.0 million, or $0.04 per share. (See the "Reconciliation of Net Income (loss) 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 nine months ended September 30, 2018 was $294.9 million, an increase of 126% compared to $130.3 million for the nine months ended September 30, 2017. The increase is primarily due to higher realized prices for crude oil and NGLs, lower spending on plug and abandonment activities and $27.0 million in cash advance from joint venture partners.
Adjusted EBITDA for the third quarter of 2018 was $92.2 million and Adjusted EBITDA margin was 60%, compared to Adjusted EBITDA of $57.2 million and Adjusted EBITDA margin of 52% for the third 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: On October 18, 2018, we closed on a major debt refinancing, which reduced total debt principal outstanding from $903 million to $625 million, simplified the capital structure and extended the maturities of our revolving credit facility and high yield debt to 2022 and 2023, respectively, while maintaining strong liquidity.
We issued $625 million of new 9.75% senior second lien notes due November 2023. The net proceeds from the issuance, along with cash on hand and borrowings on the revolving credit facility are being used to retire all of the Company's previously outstanding notes.
Concurrently, the Company entered into a Sixth Amended and Restated Credit Agreement which provides for a revolving credit and letter of credit facility with an initial borrowing base of $250 million. The revolving credit facility will mature on October 18, 2022. Currently, we have $61 million borrowings on the revolving bank credit facility and $9.7 million of letters of credit outstanding.
Total liquidity on October 18, 2018 was $220.1 million, consisting of an unrestricted cash balance of $40.8 million and $179.3 million of availability under our revolving bank credit facility.
Capital Expenditures: Our capital expenditures for oil and gas properties on an accrual basis for the nine months of 2018 were $59.2 million, compared to $79.1 million for the 2017 period. In addition, we acquired a 9.375% interest in the Heidelberg field for $16.8 million. The 2018 period reflects a net reimbursement from Monza Energy LLC of approximately $20 million for W&T's costs associated with wells drilled or were being drilled prior to the partial interests being contributed by W&T to Monza. During the nine months ended September 30, 2018, we completed the SS 359 A-17 well, drilled and completed the SS 359 A-5 ST well, and drilled the SS 359 A-19 well at Mahogany field; drilled and completed the A-10 ST well and the A-12 well at Viosca Knoll 823 ("Virgo"); and drilled the ST 320 A-2 well at Ewing Bank 910 field. At September 30, 2018 there were two wells being completed and one well being drilled.
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, 100% working interest): The SS 359 A-19 well was drilled to total depth and found high quality net pay in multiple field pay sands with better than expected reservoir characteristics. Currently, the well is being completed and should be on production before year-end 2018. Following the A-19 well completion, the platform rig will drill the A-20 development well targeting the T-Sand.
Ewing Bank 910 Field Area (non-operated wells, deepwater, in JV Drilling Program): The ST 320 A-2 exploratory well was successfully drilled from the South Timbalier 311 platform that is part of the Ewing Bank 910 field. The well logged approximately 163 vertical feet of net pay, which also exceeded pre-drill estimates, and is currently being completed. We expect to have the well on production via existing infrastructure before year-end 2018. W&T has a 10.8% interest in the ST 320 A-2 well before certain thresholds are met.
Following the completion of the ST 320 A-2 well, the rig will spud the ST 320 A-3 well, another low-risk exploration opportunity in the Ewing Bank 910 field. We believe stratigraphic information from a high quality thick Miocene sand that was penetrated in another offset well has reduced the risk on the ST 320 A-3 prospect. W&T has a 10.8% interest in the ST 320 A-3 well before certain thresholds are met.
Viosca Knoll 823 "Virgo" (operated, shelf, in JV Drilling Program): The Virgo field platform rig drilled and completed the A-12 well in block VK 779, which is currently on flow-back. The well found 60 feet of net vertical pay. The rig has commenced drilling the A-13 well, which is expected to reach total depth in November or December of 2018 with production expected to commence by year-end 2018 or early 2019. W&T has a 16% interest in the A-12 and a 23.9% interest in the A-13 well before certain thresholds are met.
Well Recompletions and Workovers: During the third quarter of 2018 we performed four recompletions that added approximately 1,673 Boe per day of initial production and six workovers that added approximately 265 Boe per day of initial production.
Fourth Quarter and Full Year 2018 Production and Expense Guidance
Our guidance for the fourth 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".
Production | Fourth Quarter 2018 | Prior Full 2018 | Revised Full |
Oil and NGL's (MMBbls) | 1.9 - 2.1 | 7.8 - 8.6 | 7.9 - 8.1 |
Natural Gas (Bcf) | 7.4 - 8.2 | 32.2 - 35.6 | 32.0 - 32.8 |
Total (Bcfe) | 18.8 - 20.7 | 79.0 - 87.4 | 79.4 - 81.4 |
Total (MMBoe) | 3.1 - 3.5 | 13.2 - 14.6 | 13.2 - 13.6 |
Operating Expenses | Fourth Quarter | Prior Full | Revised Full |
Lease operating expenses | $38 - $42 | $159 - $176 | $143 - $158 |
Gathering, transportation & | |||
production taxes | $6 - $7 | $23 - $26 | $22 - $25 |
General and administrative | $14 - $15 | $56 - $62 | $57 -$63 |
Income tax rate benefit | 0% | 0% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, November 1, 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 through November 9, 2018 and may be accessed by calling 201-612-7415 and using the passcode 13683861#.
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 and Cautionary 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 | ||||||||||||||
Condensed Consolidated Statements of Income (Loss) | ||||||||||||||
(Unaudited) | ||||||||||||||
Three Months Ended | Nine Months Ended | |||||||||||||
September 30, | September 30, | |||||||||||||
2018 | 2017 | 2018 | 2017 | |||||||||||
(In thousands, except per share data) | ||||||||||||||
Revenues: | ||||||||||||||
Oil | $ | 119,482 | $ | 78,055 | $ | 333,406 | $ | 248,648 | ||||||
NGLs | 10,087 | 6,605 | 28,481 | 22,401 | ||||||||||
Natural gas | 22,641 | 24,113 | 71,485 | 83,129 | ||||||||||
Other | 1,249 | 1,508 | 3,912 | 3,819 | ||||||||||
Total revenues | 153,459 | 110,281 | 437,284 | 357,997 | ||||||||||
Operating costs and expenses: | ||||||||||||||
Lease operating expenses | 37,430 | 35,134 | 109,855 | 106,817 | ||||||||||
Gathering, transportation costs and production taxes | 6,211 | 4,448 | 17,090 | 16,939 | ||||||||||
Depreciation, depletion, amortization and accretion | 36,969 | 36,489 | 114,807 | 116,843 | ||||||||||
General and administrative expenses | 15,990 | 15,631 | 45,248 | 45,379 | ||||||||||
Derivative (gain) loss | (288) | 2,879 | 5,931 | (4,765) | ||||||||||
Total costs and expenses | 96,312 | 94,581 | 292,931 | 281,213 | ||||||||||
Operating income | 57,147 | 15,700 | 144,353 | 76,784 | ||||||||||
Interest expense | 11,630 | 11,554 | 35,100 | 34,284 | ||||||||||
Gain on exchange of debt | - | - | - | 7,811 | ||||||||||
Other (income) expense, net | (885) | (41) | (1,093) | 5,073 | ||||||||||
Income before income tax expense (benefit) | 46,402 | 4,187 | 110,346 | 45,238 | ||||||||||
Income tax expense (benefit) | 142 | 5,484 | 363 | (11,079) | ||||||||||
Net income (loss) | $ | 46,260 | $ | (1,297) | $ | 109,983 | $ | 56,317 | ||||||
Basic and diluted earnings (loss) per common share | $ | 0.32 | $ | (0.01) | $ | 0.76 | $ | 0.39 | ||||||
Weighted average common shares outstanding | 138,972 | 137,575 | 138,917 | 137,547 | ||||||||||
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Three Months Ended | ||||||||||||
September 30, | Variance | |||||||||||
2018 | 2017 | Variance | ||||||||||
Net sales volumes: | ||||||||||||
Oil (MBbls) | 1,717 | 1,700 | 17 | 1.0% | ||||||||
NGL (MBbls) | 318 | 299 | 19 | 6.4% | ||||||||
Oil and NGLs (MBbls) | 2,036 | 1,999 | 37 | 1.9% | ||||||||
Natural gas (MMcf) | 7,939 | 8,130 | (191) | -2.3% | ||||||||
Total oil and natural gas (MBoe) (1) | 3,359 | 3,354 | 5 | 0.1% | ||||||||
Total oil and natural gas (MMcfe) (1) | 20,152 | 20,125 | 27 | 0.1% | ||||||||
Average daily equivalent sales (Boe/d) | 36.5 | 36.5 | 0.0 | 0.1% | ||||||||
Average daily equivalent sales (MMcfe/d) | 219.0 | 218.8 | 0.3 | 0.1% | ||||||||
Average realized sales prices: | ||||||||||||
Oil ($/Bbl) | $ | 69.57 | $ | 45.92 | $ | 23.65 | 51.5% | |||||
NGLs ($/Bbl) | 31.70 | 22.07 | 9.63 | 43.6% | ||||||||
Oil and NGLs ($/Bbl) | 63.65 | 42.35 | 21.30 | 50.3% | ||||||||
Natural gas ($/Mcf) | 2.85 | 2.97 | (0.12) | -4.0% | ||||||||
Barrel of oil equivalent ($/Boe) | 45.32 | 32.43 | 12.89 | 39.7% | ||||||||
Natural gas equivalent ($/Mcfe) | 7.55 | 5.40 | 2.15 | 39.8% | ||||||||
Average per Boe ($/Boe): | ||||||||||||
Lease operating expenses | $ | 11.14 | $ | 10.48 | $ | 0.66 | 6.3% | |||||
Gathering and transportation costs and production taxes | 1.85 | 1.33 | 0.52 | 39.1% | ||||||||
Depreciation, depletion, amortization and accretion | 11.01 | 10.88 | 0.13 | 1.2% | ||||||||
General and administrative expenses | 4.76 | 4.66 | 0.10 | 2.1% | ||||||||
Average per Mcfe ($/Mcfe): | ||||||||||||
Lease operating expenses | $ | 1.86 | $ | 1.75 | $ | 0.11 | 6.3% | |||||
Gathering and transportation costs and production taxes | 0.31 | 0.22 | 0.09 | 40.9% | ||||||||
Depreciation, depletion, amortization and accretion | 1.83 | 1.81 | 0.02 | 1.1% | ||||||||
General and administrative expenses | 0.79 | 0.78 | 0.01 | 1.3% | ||||||||
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Nine Months Ended | ||||||||||||
September 30, | Variance | |||||||||||
2018 | 2017 | Variance | ||||||||||
Net sales volumes: | ||||||||||||
Oil (MBbls) | 5,012 | 5,428 | (416) | -7.7% | ||||||||
NGL (MBbls) | 985 | 1,024 | (39) | -3.8% | ||||||||
Oil and NGLs (MBbls) | 5,998 | 6,451 | (453) | -7.0% | ||||||||
Natural gas (MMcf) | 24,648 | 28,005 | (3,357) | -12.0% | ||||||||
Total oil and natural gas (MBoe) (1) | 10,106 | 11,119 | (1,013) | -9.1% | ||||||||
Total oil and natural gas (MMcfe) (1) | 60,633 | 66,714 | (6,081) | -9.1% | ||||||||
Average daily equivalent sales (Boe/d) | 37.0 | 40.7 | (3.7) | -9.1% | ||||||||
Average daily equivalent sales (MMcfe/d) | 222.1 | 244.4 | (22.3) | -9.1% | ||||||||
Average realized sales prices: | ||||||||||||
Oil ($/Bbl) | $ | 66.52 | $ | 45.81 | $ | 20.71 | 45.2% | |||||
NGLs ($/Bbl) | 28.91 | 21.88 | 7.03 | 32.1% | ||||||||
Oil and NGLs ($/Bbl) | 60.34 | 42.01 | 18.33 | 43.6% | ||||||||
Natural gas ($/Mcf) | 2.90 | 2.97 | (0.07) | -2.4% | ||||||||
Barrel of oil equivalent ($/Boe) | 42.88 | 31.85 | 11.03 | 34.6% | ||||||||
Natural gas equivalent ($/Mcfe) | 7.15 | 5.31 | 1.84 | 34.7% | ||||||||
Average per Boe ($/Boe): | ||||||||||||
Lease operating expenses | $ | 10.87 | $ | 9.61 | $ | 1.26 | 13.1% | |||||
Gathering and transportation costs and production taxes | 1.69 | 1.52 | 0.17 | 11.2% | ||||||||
Depreciation, depletion, amortization and accretion | 11.36 | 10.51 | 0.85 | 8.1% | ||||||||
General and administrative expenses | 4.48 | 4.08 | 0.40 | 9.8% | ||||||||
Average per Mcfe ($/Mcfe): | ||||||||||||
Lease operating expenses | $ | 1.81 | $ | 1.60 | $ | 0.21 | 13.1% | |||||
Gathering and transportation costs and production taxes | 0.28 | 0.25 | 0.03 | 12.0% | ||||||||
Depreciation, depletion, amortization and accretion | 1.89 | 1.75 | 0.14 | 8.0% | ||||||||
General and administrative expenses | 0.75 | 0.68 | 0.07 | 10.3% | ||||||||
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Balance Sheets | |||||||
(Unaudited) | |||||||
September 30, | December 31, | ||||||
2018 | 2017 | ||||||
(In thousands, except | |||||||
Assets | |||||||
Current assets: | |||||||
Cash and cash equivalents | $ | 339,063 | $ | 99,058 | |||
Receivables: | |||||||
Oil and natural gas sales | 49,482 | 45,443 | |||||
Joint interest | 16,493 | 19,754 | |||||
Income taxes | 65,240 | 13,006 | |||||
Total receivables | 131,215 | 78,203 | |||||
Prepaid expenses and other assets | 19,699 | 13,419 | |||||
Total current assets | 489,977 | 190,680 | |||||
Property and equipment | 8,166,969 | 8,123,875 | |||||
Less accumulated depreciation, depletion and amortization | 7,644,188 | 7,544,859 | |||||
Net property and equipment | 522,781 | 579,016 | |||||
Restricted deposits for asset retirement obligations | 20,577 | 25,394 | |||||
Income tax receivable | - | 52,097 | |||||
Other assets | 69,014 | 60,393 | |||||
Total assets | $ | 1,102,349 | $ | 907,580 | |||
Liabilities and Shareholders' Deficit | |||||||
Current liabilities: | |||||||
Accounts payable | $ | 95,502 | $ | 79,667 | |||
Undistributed oil and natural gas proceeds | 34,225 | 20,129 | |||||
Advances from joint interest partners | 31,012 | 3,998 | |||||
Asset retirement obligations | 30,207 | 23,613 | |||||
Current maturities of long-term debt: | |||||||
Principal | 189,829 | - | |||||
Carrying value adjustments | 34,985 | 22,925 | |||||
Current maturities of long-term debt - carrying value | 224,814 | 22,925 | |||||
Accrued liabilities | 31,058 | 17,930 | |||||
Total current liabilities | 446,818 | 168,262 | |||||
Long-term debt: | |||||||
Principal | 713,365 | 889,790 | |||||
Carrying value adjustments | 45,758 | 79,337 | |||||
Long-term debt, less current portion - carrying value | 759,123 | 969,127 | |||||
Asset retirement obligations, less current portion | 283,009 | 276,833 | |||||
Other liabilities | 73,175 | 66,866 | |||||
Commitments and contingencies | - | - | |||||
Shareholders' deficit: | |||||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 142,022,971 issued and 139,153,798 outstanding at September 30, 2018; 141,960,462 issued and 139,091,289 outstanding at December 31, 2017 | 1 | 1 | |||||
Additional paid-in capital | 549,569 | 545,820 | |||||
Retained earnings (deficit) | (985,179) | (1,095,162) | |||||
Treasury stock, at cost | (24,167) | (24,167) | |||||
Total shareholders' deficit | (459,776) | (573,508) | |||||
Total liabilities and shareholders' deficit | $ | 1,102,349 | $ | 907,580 | |||
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||
Condensed Consolidated Statements of Cash Flows | ||||||||
(Unaudited) | ||||||||
Nine Months Ended | ||||||||
2018 | 2017 | |||||||
(In thousands) | ||||||||
Operating activities: | ||||||||
Net Income | $ | 109,983 | $ | 56,317 | ||||
Adjustments to reconcile net income to net cash provided by operating activities: | ||||||||
Depreciation, depletion, amortization and accretion | 114,807 | 116,843 | ||||||
Gain on exchange of debt | - | (7,811) | ||||||
Amortization of debt items and other items | 1,796 | 1,271 | ||||||
Share-based compensation | 3,808 | 5,449 | ||||||
Derivative (gain) loss | 5,931 | (4,765) | ||||||
Cash receipts (payments) on derivative settlements, net | (3,091) | 3,924 | ||||||
Deferred income taxes | 363 | 321 | ||||||
Changes in operating assets and liabilities: | ||||||||
Oil and natural gas receivables | (4,039) | 3,906 | ||||||
Joint interest receivables | 3,261 | 8 | ||||||
Insurance reimbursements | - | 31,740 | ||||||
Income taxes | (139) | 320 | ||||||
Prepaid expenses and other assets | (8,467) | 2,194 | ||||||
Escrow deposit - Apache lawsuit | - | (49,500) | ||||||
Asset retirement obligation settlements | (22,764) | (56,226) | ||||||
Cash advances from JV partners | 27,014 | (786) | ||||||
Accounts payable, accrued liabilities and other | 66,389 | 27,115 | ||||||
Net cash provided by operating activities | 294,852 | 130,320 | ||||||
Investing activities: | ||||||||
Investment in oil and natural gas properties and equipment | (59,161) | (79,088) | ||||||
Changes in operating assets and liabilities associated with investing activities | (20,261) | 5,679 | ||||||
Acquisition of property interest | (16,782) | - | ||||||
Proceeds from sale of assets | 50,474 | - | ||||||
Purchases of furniture, fixtures and other | - | (905) | ||||||
Net cash used in investing activities | (45,730) | (74,314) | ||||||
Financing activities: | ||||||||
Payment of interest on 1.5 Lien Term Loan | (6,171) | (6,170) | ||||||
Payment of interest on 2nd Lien PIK Toggle Notes | (2,920) | (7,335) | ||||||
Payment of interest on 3rd Lien PIK Toggle Notes | - | (6,201) | ||||||
Other | (26) | (372) | ||||||
Net cash used in financing activities | (9,117) | (20,078) | ||||||
Increase in cash and cash equivalents | 240,005 | 35,928 | ||||||
Cash and cash equivalents, beginning of period | 99,058 | 70,236 | ||||||
Cash and cash equivalents, end of period | $ | 339,063 | $ | 106,164 | ||||
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 (Loss) to Net Income Excluding Special Items
"Net Income Excluding Special Items" does not include the unrealized commodity derivative (gain) loss, bad debt reserve, 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.
Three Months Ended | Nine Months Ended September 30, | |||||||||||||||
2018 | 2017 | 2018 | 2017 | |||||||||||||
(In thousands, except per share amounts) | ||||||||||||||||
(Unaudited) | ||||||||||||||||
Net income (loss) | $ | 46,260 | $ | (1,297) | $ | 109,983 | $ | 56,317 | ||||||||
Unrealized commodity derivative (gain) loss | (2,230) | 4,595 | 2,840 | (841) | ||||||||||||
Bad debt reserve | 111 | 385 | 654 | 860 | ||||||||||||
Gain on exchange of debt | - | - | - | (7,811) | ||||||||||||
Apache lawsuit | - | - | - | 6,285 | ||||||||||||
EC 321 settlement | - | - | - | (1,109) | ||||||||||||
Penalties, litigation and related interest | - | - | 579 | 1,820 | ||||||||||||
Income tax adjustment for the items above | 6 | (1,743) | (12) | 279 | ||||||||||||
Income tax adjustment for effective tax rate for the quarter | - | 4,019 | - | - | ||||||||||||
Net income excluding special items | $ | 44,147 | $ | 5,959 | $ | 114,044 | $ | 55,800 | ||||||||
Basic and diluted income per common share, excluding special items | $ | 0.30 | $ | 0.04 | $ | 0.79 | $ | 0.39 | ||||||||
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Reconciliation of Net Income (Loss) to Adjusted EBITDA
We define EBITDA as net income plus income tax expense (benefit), net interest expense, and depreciation, depletion, amortization and accretion. Adjusted EBITDA excludes the unrealized commodity derivative (gain) loss, bad debt reserve, 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 (loss) to EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Three Months Ended | Nine Months Ended | |||||||||||||||
2018 | 2017 | 2018 | 2017 | |||||||||||||
(In thousands) | ||||||||||||||||
(Unaudited) | ||||||||||||||||
Net income (loss) | $ | 46,260 | $ | (1,297) | $ | 109,983 | $ | 56,317 | ||||||||
Income tax expense (benefit) | 142 | 5,484 | 363 | (11,079) | ||||||||||||
Net interest expense | 10,949 | 11,513 | 34,211 | 34,231 | ||||||||||||
Depreciation, depletion, amortization and accretion | 36,969 | 36,489 | 114,807 | 116,843 | ||||||||||||
EBITDA | 94,320 | 52,189 | 259,364 | 196,312 | ||||||||||||
Adjustments: | ||||||||||||||||
Unrealized commodity derivative (gain) loss | (2,230) | 4,595 | 2,840 | (841) | ||||||||||||
Bad debt reserve | 111 | 385 | 654 | 860 | ||||||||||||
Gain on exchange of debt | - | - | - | (7,811) | ||||||||||||
Apache lawsuit | - | - | - | 6,285 | ||||||||||||
EC 321 settlement | - | - | - | (1,109) | ||||||||||||
Civil penalties and other litigation | - | - | (194) | 1,820 | ||||||||||||
Adjusted EBITDA | $ | 92,201 | $ | 57,169 | $ | 262,664 | $ | 195,516 | ||||||||
Adjusted EBITDA Margin | 60% | 52% | 60% | 55% | ||||||||||||
CONTACT: | Lisa Elliott | Janet Yang |
Dennard Lascar Investor Relations | VP & CFO | |
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-third-quarter-2018-results-and-fourth-quarter-2018-guidance-300741753.html
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 18, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) ("W&T Offshore" or the "Company") announced today that it has closed transactions to effect a refinancing of substantially all of its outstanding indebtedness. The Company today closed its previously announced private offering of $625.0 million in aggregate principal amount of 9.75% Senior Second Lien Notes due 2023 (the "New Notes") which priced at par. The Company also entered into a Sixth Amended and Restated Credit Agreement which provides for a revolving credit and letter of credit facility with an initial borrowing base of $250.0 million.
The Company used net proceeds from the offering of New Notes, borrowings under its new amended and restated revolving credit facility and cash on hand to (i) repay and retire its outstanding $75.0 million 11.00% 1.5 Lien Term Loan and $300.0 million 9.00% Second Lien Term Loan and (ii) redeem or repurchase in full all of its outstanding 8.500% Senior Notes due 2019, 9.00%/10.75% Senior Second Lien PIK Toggle Notes due 2020 and 8.50%/10.00% Senior Third Lien PIK Toggle Notes due 2021 (collectively, the "Existing Notes").
The Company also announced its repurchase and retirement of $464.4 million in aggregate principal of its Existing Notes pursuant to its acceptance of early tenders of Existing Notes validly tendered and not withdrawn by holders pursuant to the Company's previously announced offer to purchase for cash any and all of its outstanding Existing Notes. The remaining outstanding $63.8 million in aggregate principal of its Existing Notes was irrevocably called for redemption on November 17, 2018 under the terms of the applicable indenture governing each issue of Existing Notes. Sufficient redemption funds were deposited in trust with the indenture trustee to satisfy and discharge all of the Company's obligations under the Existing Notes and the respective indentures, and settlement of such redemptions will occur on November 19, 2018, the next business day following the redemption date.
The Company's offer to purchase remaining Existing Notes will expire at 11:59 p.m., New York City time, on October 31, 2018, unless extended. Outstanding Existing Notes validly tendered and not withdrawn and accepted by the Company pursuant to the terms of the previously announced offer to purchase will receive the tender offer consideration described in the offer to purchase dated October 3, 2018, which does not include the early tender premium, plus accrued and unpaid interest.
The New Notes are not being registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws; and unless so registered, the New Notes may not be offered or sold in the United States except pursuant to an exemption from, or in a transaction not subject to, the registration requirements of the Securities Act and applicable state securities laws. The New Notes were being offered only to qualified institutional buyers in the United States under Rule 144A and to non-U.S. investors outside the United States pursuant to Regulation S.
This press release does not constitute an offer to sell or a solicitation of an offer to buy, or a sale of, the New Notes or any other securities, nor does it constitute an offer, solicitation or sale in any jurisdiction in which such offer, solicitation or sale is unlawful.
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.
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, 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.
CONTACT: | Lisa Elliott | Janet Yang |
Dennard Lascar Investor Relations | Vice President & Chief Financial Officer | |
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-inc-announces-closing-of-major-debt-refinancing-300733733.html
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 16, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its third quarter 2018 financial and operational results after the market closes on Wednesday, October 31, 2018. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Thursday, November 1, 2018, at 10:00 a.m. Eastern Time (9:00 a.m. Central Time).
By Phone: | Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through November 8, 2018 by dialing 1-201-612-7415 and using the passcode 13683861. |
By Webcast: | Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Events Calendar." A replay will be available shortly after the call. |
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.
CONTACT: | Lisa Elliott | Janet Yang |
Dennard Lascar Investor Relations | VP & CFO | |
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-third-quarter-2018-financial-and-operational-results-release-and-conference-call-schedule-300731540.html
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 5, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) ("W&T Offshore" or the "Company") announced today the pricing of its previously announced private offering of $625.0 million in aggregate principal amount of senior second lien notes due 2023 (the "Notes"). The Notes, which priced at par, will mature on November 1, 2023, and will pay interest at an annual rate of 9.75%.
The closing of the offering of the Notes is expected to occur on October 18, 2018, subject to customary closing conditions. W&T Offshore intends to use the net proceeds of the offering, together with borrowings from a proposed amended revolving bank credit facility and cash on hand, to (i) repay and retire its outstanding 11.00% 1.5 Lien Term Loan and 9.00% Second Lien Term Loan and (ii) redeem or repurchase in full all of its outstanding 8.500% Senior Unsecured Notes due 2019, 9.00%/10.75% Second Lien PIK Toggle Notes due 2020 and 8.50%/10.00% Third Lien PIK Toggle Notes due 2021. In connection with the offering, W&T Offshore has obtained a commitment letter from three commercial banks for a proposed amended revolving bank credit facility with initial bank lending commitments and borrowing base of $250 million that is expected to close concurrently with the closing of the offering of the Notes.
The Notes have not been registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws; and unless so registered, the securities may not be offered or sold in the United States except pursuant to an exemption from, or in a transaction not subject to, the registration requirements of the Securities Act and applicable state securities laws. The Notes are being offered only to qualified institutional buyers in the United States under Rule 144A and to non-U.S. investors outside the United States pursuant to Regulation S.
This press release does not constitute an offer to sell or a solicitation of an offer to buy, or a sale of, the Notes or any other securities, nor does it constitute an offer, solicitation or sale in any jurisdiction in which such offer, solicitation or sale is unlawful.
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.
Forward-Looking Statements
This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act 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.
CONTACT: | Lisa Elliott | Janet Yang | |
Dennard Lascar Investor Relations | VP & CFO | ||
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-inc-announces-pricing-of-625-million-offering-of-senior-second-lien-notes-300726732.html
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 5, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) ("W&T Offshore" or the "Company") announced today the pricing of its previously announced private offering of $625.0 million in aggregate principal amount of senior second lien notes due 2023 (the "Notes"). The Notes, which priced at par, will mature on November 1, 2023, and will pay interest at an annual rate of 9.75%.
The closing of the offering of the Notes is expected to occur on October 18, 2018, subject to customary closing conditions. W&T Offshore intends to use the net proceeds of the offering, together with borrowings from a proposed amended revolving bank credit facility and cash on hand, to (i) repay and retire its outstanding 11.00% 1.5 Lien Term Loan and 9.00% Second Lien Term Loan and (ii) redeem or repurchase in full all of its outstanding 8.500% Senior Unsecured Notes due 2019, 9.00%/10.75% Second Lien PIK Toggle Notes due 2020 and 8.50%/10.00% Third Lien PIK Toggle Notes due 2021. In connection with the offering, W&T Offshore has obtained a commitment letter from three commercial banks for a proposed amended revolving bank credit facility with initial bank lending commitments and borrowing base of $250 million that is expected to close concurrently with the closing of the offering of the Notes.
The Notes have not been registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws; and unless so registered, the securities may not be offered or sold in the United States except pursuant to an exemption from, or in a transaction not subject to, the registration requirements of the Securities Act and applicable state securities laws. The Notes are being offered only to qualified institutional buyers in the United States under Rule 144A and to non-U.S. investors outside the United States pursuant to Regulation S.
This press release does not constitute an offer to sell or a solicitation of an offer to buy, or a sale of, the Notes or any other securities, nor does it constitute an offer, solicitation or sale in any jurisdiction in which such offer, solicitation or sale is unlawful.
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.
Forward-Looking Statements
This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act 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.
CONTACT: | Lisa Elliott | Janet Yang | |
Dennard Lascar Investor Relations | VP & CFO | ||
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-inc-announces-pricing-of-625-million-offering-of-senior-second-lien-notes-300725567.html
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 3, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it has commenced cash tender offers (each, a "Tender Offer" and collectively, the "Tender Offers") for any and all of its outstanding 8.500% Senior Notes due 2019 (the "2019 Notes"), 9.00%/10.75% Senior Second Lien PIK Toggle Notes due 2020 (the "2020 Notes") and 8.50%/10.00% Senior Third Lien PIK Toggle Notes due 2021 (the "2021 Notes" and together with the 2019 Notes and 2020 Notes, the "Notes").
The Tender Offers are scheduled to expire at 11:59 p.m., New York City time, on October 31, 2018, unless extended or earlier terminated (the "Expiration Time"). Holders who validly tender their Notes before 5:00 p.m., New York City time, on October 17, 2018, unless extended (the "Early Tender Date"), will be eligible to receive the Total Consideration (as defined below). The Tender Offers provide for an early settlement option, so that holders whose Notes are validly tendered and not subsequently validly withdrawn prior to the Early Tender Date and accepted for purchase could receive payment as early as October 18, 2018. Tenders of Notes may be validly withdrawn until the Withdrawal Time (defined below). The following table sets forth the Tender Offer Consideration, the Early Tender Premium (defined below) and the Total Consideration for each $1,000 aggregate principal amount of Notes of each series.
Aggregate Principal Amount | Series of | CUSIP/ISIN | Tender Offer | Early | Total |
$189,829,000 | 2019 Notes | CUSIP No. ISIN No. | $973.75 | $30.00 | $1,003.75 |
$177,513,418 | 2020 Notes | CUSIP Nos. ISIN Nos. | $996.50 | $30.00 | $1,026.50 |
$160,851,884 | 2021 Notes | CUSIP Nos. ISIN Nos. | $1,016.50 | $30.00 | $1,046.25 |
Holders tendering prior to the Early Tender Date will be eligible to receive the "Tender Offer Consideration" and the early tender premium set forth in the table above (the "Early Tender Premium" and with respect to each series of Notes, together with the Tender Offer Consideration, the "Total Consideration"). Holders tendering after the Early Tender Date will be eligible to receive only the "Tender Offer Consideration," which does not include the Early Tender Premium. Holders whose Notes are purchased in the Tender Offers will also receive accrued and unpaid interest from the most recent interest payment date at the applicable cash interest rate for the Notes to, but not including, the applicable settlement date. Holders who validly tender their Notes before the Early Tender Date will be eligible to receive payment on the initial settlement date, which may be as early as October 18, 2018, and holders tendering after the Early Tender Date and prior to the Expiration Time will be eligible to receive payment on the final settlement date, which is expected to be November 1, 2018.
Tendered Notes may be withdrawn before 5:00 p.m., New York City time, on October 17, 2018 (unless extended, the "Withdrawal Time"), but not thereafter, except under limited circumstances. Any extension, termination or amendment of any of the Tender Offers will be followed as promptly as practicable by a public announcement thereof.
Each Tender Offer is subject to the satisfaction of certain conditions including: (1) consummation of a capital markets debt offering raising proceeds in an amount sufficient, when taken together with cash on hand and borrowings under W&T Offshore's revolving bank credit facility, to pay the aggregate consideration for all the tendered Notes, plus all fees and expenses incurred in connection with the Tender Offers, including accrued and unpaid interest on such Notes and to repay outstanding term loan indebtedness and (2) certain other customary conditions.
We currently intend to exercise our right to redeem any Notes that remain outstanding after the Tender Offers, although we have no legal obligation to do so.
The complete terms and conditions of the Tender Offers are described in the Offer to Purchase dated October 3, 2018, copies of which may be obtained from D.F. King & Co., Inc., the tender agent and information agent for the Tender Offers, at (800) 207-2872 (US toll free) or, for banks and brokers, (212) 269-5550, or email at wti@dfking.com.
W&T Offshore has engaged Morgan Stanley & Co. LLC to act as the exclusive dealer manager in connection with the Tender Offers. Questions regarding the terms of the Tender Offers may be directed to Morgan Stanley & Co. LLC, Liability Management Group, at (800) 624-1808 (US toll free) and (212) 761-1057 (collect).
None of W&T Offshore, the dealer manager or the tender agent and information agent or their respective affiliates are making any recommendation as to whether or not holders should tender all or any portion of their Notes in the Tender Offers.
This announcement is not an offer to purchase or a solicitation of an offer to purchase with respect to any securities. The Tender Offers are being made solely by the Offer to Purchase dated October 3, 2018. The Tender Offers are not being made to holders of Notes in any jurisdiction in which the making or acceptance thereof would not be in compliance with the securities or other laws of such jurisdiction.
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.
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, 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.
CONTACT: | Lisa Elliott | Janet Yang |
Dennard Lascar Investor Relations | VP & CFO | |
713-529-6600 | 713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Sept. 27, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) ("W&T Offshore") today announced that, subject to market conditions, it intends to offer $625 million in aggregate principal amount of senior second lien notes due 2023 (the "Notes") in a private placement to eligible purchasers.
W&T Offshore intends to use the net proceeds of this offering, together with borrowings from a proposed amended revolving bank credit facility and cash on hand, to (i) repay and retire its outstanding 11.00% 1.5 Lien Term Loan and 9.00% Second Lien Term Loan and (ii) redeem or repurchase in full all of its outstanding 8.500% Senior Unsecured Notes due 2019, 9.00%/10.75% Second Lien PIK Toggle Notes due 2020 and 8.50%/10.00% Third Lien PIK Toggle Notes due 2021. In connection with this offering, W&T Offshore has obtained a commitment letter from three commercial banks for a proposed amended revolving bank credit facility with initial bank lending commitments and borrowing base of $250 million that is expected to close concurrently with the closing of this offering of Notes.
The Notes to be offered have not been registered under the Securities Act of 1933 as amended, (the "Securities Act"), or any state securities laws; and unless so registered, the securities may not be offered or sold in the United States except pursuant to an exemption from, or in a transaction not subject to, the registration requirements of the Securities Act and applicable state securities laws. The Notes will be offered only to qualified institutional buyers in the United States under Rule 144A and to non-U.S. investors outside the United States pursuant to Regulation S.
This press release does not constitute an offer to sell or a solicitation of an offer to buy, or a sale of, the Notes or any other securities, nor does it constitute an offer, solicitation or sale in any jurisdiction in which such offer, solicitation or sale is unlawful.
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.
Forward-Looking Statements
This press release contains forward-looking statements within the meaning of Section 27A of the Securities Act 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.
CONTACT: | Lisa Elliott | Janet Yang |
Dennard Lascar Investor Relations | VP & CFO | |
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-inc-announces-launch-of-625-million-offering-of-senior-second-lien-notes-300720683.html
SOURCE W&T Offshore, Inc.
HOUSTON, Sept. 25, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today announced that it has entered into a definitive purchase and sale agreement to divest its ownership in overriding royalty interests in the Permian Basin for $56.8 million. The transaction, subject to customary closing conditions and adjustments, is expected to close on or before October 1, 2018.
The Company also announced that it has successfully drilled an exploration well from the South Timbalier 311 platform that is part of the Ewing Bank 910 field. The ST 320 A-2 exploratory well has reached total depth and is being prepared for completion. The Company logged approximately 163 feet of net hydrocarbon, which exceeds pre-drill estimates. W&T expects to have the well on production via existing infrastructure before year-end 2018.
Following the completion of the ST 320 A-2 well, the rig will spud the ST 320 A-3 well, another low-risk exploration opportunity in the Ewing Bank 910 field. Stratigraphic information from a high quality thick Miocene sand that was penetrated up-hole in the ST 320 A-2 well has lowered the perceived risk on the ST 320 A-3 oil prospect.
Both of these wells in the Ewing Bank 910 field are part of a drilling joint venture program established by W&T and private investors in 2018 ("JV Drilling Program"). Prior to inclusion of these wells in the JV Drilling Program, W&T's working interest in these wells were 36%. As a result of the JV Drilling Program and other promoted working interests at the ST 320 A-2 well, W&T is expected to contribute 4.8% of the total capital expenditures and will receive 10.8% of the net revenues less expenses until certain thresholds are met, at which time W&T's effective interest in this well will increase to 13.8%.
Tracy Krohn, W&T Offshore's Chairman and CEO, stated, "The divestiture of our non-core, non-operated onshore asset will enhance our already strong cash position as we optimize our balance sheet for future growth. We are continuing to have excellent drilling success in the Gulf of Mexico and delivering solid results for our JV Drilling Program. The ST 320 A-2 well success further supports our plan to execute and bring forward our high-quality prospect inventory."
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.
CONTACT: | Lisa Elliott | Janet Yang |
Dennard Lascar Investor Relations | VP & CFO | |
713-529-6600 | 713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-signs-definitive-agreement-to-sell-non-core-asset-300717956.html
SOURCE W&T Offshore, Inc.
HOUSTON, Sept. 4, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today announced that Tracy Krohn, W&T Offshore's Chairman and CEO, is participating in the Barclays CEO Energy-Power Conference in New York City and is scheduled to make a presentation today from 3:45 pm to 4:20 pm Eastern Time.
Mr. Krohn's presentation to the conference will be broadcast live over the Internet and be available for replay. The webcast link to the audio presentation and accompanying slides can be accessed from the Company's website.
In connection with W&T's participation in the conference, W&T has updated its investor presentation, which is available from the Investor Relations section of the Company's website at www.wtoffshore.com.
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.
CONTACT: Lisa Elliott |
Janet Yang |
Dennard Lascar Investor Relations |
VP & CFO |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-presents-at-barclays-ceo-energy-power-conference-and-updates-investor-presentation-300706029.html
SOURCE W&T Offshore, Inc.
HOUSTON, Aug. 28, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today announced that the Company will be participating in two upcoming investor conferences.
The Company's management will be meeting with investors at the Seaport Global Energy and Industrials Conference in Chicago on August 28 & 29, 2018. W&T will not be making a formal presentation. The updated investor presentation is available from the Investor Relations section of the Company's website at www.wtoffshore.com
The Company is also participating in the Barclays CEO Energy-Power Conference in New York City on September 4 & 5, 2018. Tracy Krohn, W&T Offshore's Chairman and CEO, is scheduled to make a presentation on September 4 at 3:45 pm to 4:20 pm Eastern Time. The presentation will provide an update on the Company's operations and will be broadcast over the Internet. The webcast link to the audio presentation and accompanying slides can be accessed from the Company's website.
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.
CONTACT: |
Lisa Elliott |
Janet Yang |
|
Dennard Lascar Investor Relations |
VP & CFO |
||
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-to-participate-in-upcoming-conferences-300703569.html
SOURCE W&T Offshore, Inc.
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:
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".
Third Quarter |
Full Year | |
Production |
2018 |
2018 |
Oil and NGL's (MMBbls) |
1.9 - 2.1 |
7.8 - 8.6 |
Natural Gas (Bcf) |
7.2 - 8.0 |
32.2 - 35.6 |
Total (Bcfe) |
18.5 - 20.4 |
79.0 - 87.4 |
Total (MMBoe) |
3.1 - 3.4 |
13.2 - 14.6 |
Operating Expenses |
Third Quarter |
Full Year |
($ in millions) |
2018 |
2018 |
Lease operating expenses |
$43 - $47 |
$159 - $176 |
Gathering, transportation & production taxes |
$6 - $7 |
$23 - $26 |
General and administrative |
$14 - $16 |
$56 - $62 |
Income tax rate benefit |
0% |
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 | |||||||||||
Condensed Consolidated Statements of Income (Loss) | |||||||||||
(Unaudited) | |||||||||||
Three Months Ended |
Six Months Ended | ||||||||||
June 30, |
June 30, | ||||||||||
2018 |
2017 |
2018 |
2017 | ||||||||
(In thousands, except per share data) | |||||||||||
Revenues: |
|||||||||||
Oil |
$ |
116,618 |
$ |
85,622 |
$ |
213,924 |
$ |
170,593 | |||
NGLs |
8,734 |
7,054 |
18,394 |
15,796 | |||||||
Natural gas |
22,977 |
29,258 |
48,844 |
59,016 | |||||||
Other |
1,283 |
1,389 |
2,663 |
2,311 | |||||||
Total revenues |
149,612 |
123,323 |
283,825 |
247,716 | |||||||
Operating costs and expenses: |
|||||||||||
Lease operating expenses |
35,582 |
31,519 |
72,425 |
71,683 | |||||||
Gathering, transportation costs and production taxes |
5,367 |
5,767 |
10,879 |
12,491 | |||||||
Depreciation, depletion, amortization and accretion |
39,757 |
40,364 |
77,838 |
80,354 | |||||||
General and administrative expenses |
14,220 |
16,474 |
29,258 |
29,748 | |||||||
Derivative (gain) loss |
6,219 |
(3,689) |
6,219 |
(7,644) | |||||||
Total costs and expenses |
101,145 |
90,435 |
196,619 |
186,632 | |||||||
Operating income |
48,467 |
32,888 |
87,206 |
61,084 | |||||||
Interest expense |
12,147 |
11,436 |
23,470 |
22,730 | |||||||
Gain on exchange of debt |
- |
8,056 |
- |
7,811 | |||||||
Other (income) expense, net |
125 |
5,168 |
(208) |
5,114 | |||||||
Income before income tax expense (benefit) |
36,195 |
24,340 |
63,944 |
41,051 | |||||||
Income tax expense (benefit) |
112 |
(8,975) |
221 |
(16,563) | |||||||
Net income |
$ |
36,083 |
$ |
33,315 |
$ |
63,723 |
$ |
57,614 | |||
Basic and diluted earnings per common share |
$ |
0.25 |
$ |
0.23 |
$ |
0.44 |
$ |
0.40 | |||
Weighted average common shares outstanding |
138,929 |
137,552 |
138,892 |
137,533 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||
Condensed Operating Data | ||||||||||
(Unaudited) | ||||||||||
Three Months Ended |
||||||||||
June 30, |
Variance | |||||||||
2018 |
2017 |
Variance |
Percentage(2) | |||||||
Net sales volumes: |
||||||||||
Oil (MBbls) |
1,738 |
1,923 |
(185) |
-9.6% | ||||||
NGL (MBbls) |
316 |
351 |
(35) |
-10.0% | ||||||
Oil and NGLs (MBbls) |
2,055 |
2,272 |
(217) |
-9.6% | ||||||
Natural gas (MMcf) |
8,186 |
9,890 |
(1,704) |
-17.2% | ||||||
Total oil and natural gas (MBoe) (1) |
3,419 |
3,921 |
(502) |
-12.8% | ||||||
Total oil and natural gas (MMcfe) (1) |
20,514 |
23,524 |
(3,010) |
-12.8% | ||||||
Average daily equivalent sales (Boe/d) |
37.6 |
43.1 |
(5.5) |
-12.8% | ||||||
Average daily equivalent sales (MMcfe/d) |
225.4 |
258.5 |
(33.1) |
-12.8% | ||||||
Average realized sales prices: |
||||||||||
Oil ($/Bbl) |
$ |
67.09 |
$ |
44.54 |
$ |
22.55 |
50.6% | |||
NGLs ($/Bbl) |
27.61 |
20.15 |
7.46 |
37.0% | ||||||
Oil and NGLs ($/Bbl) |
61.01 |
40.78 |
20.23 |
49.6% | ||||||
Natural gas ($/Mcf) |
2.81 |
2.96 |
(0.15) |
-5.1% | ||||||
Barrel of oil equivalent ($/Boe) |
43.38 |
31.10 |
12.28 |
39.5% | ||||||
Natural gas equivalent ($/Mcfe) |
7.23 |
5.18 |
2.05 |
39.6% | ||||||
Average per Boe ($/Boe): |
||||||||||
Lease operating expenses |
$ |
10.41 |
$ |
8.04 |
$ |
2.37 |
29.5% | |||
Gathering and transportation costs and production taxes |
1.57 |
1.47 |
0.10 |
6.8% | ||||||
Depreciation, depletion, amortization and accretion |
11.63 |
10.29 |
1.34 |
13.0% | ||||||
General and administrative expenses |
4.16 |
4.20 |
(0.04) |
-1.0% | ||||||
Average per Mcfe ($/Mcfe): |
||||||||||
Lease operating expenses |
$ |
1.73 |
$ |
1.34 |
$ |
0.39 |
29.1% | |||
Gathering and transportation costs and production taxes |
0.26 |
0.25 |
0.01 |
4.0% | ||||||
Depreciation, depletion, amortization and accretion |
1.94 |
1.72 |
0.22 |
12.8% | ||||||
General and administrative expenses |
0.69 |
0.70 |
(0.01) |
-1.4% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||
Condensed Consolidated Balance Sheets | |||||
(Unaudited) | |||||
June 30, |
December 31, | ||||
2018 |
2017 | ||||
(In thousands, except | |||||
share data) | |||||
Assets |
|||||
Current assets: |
|||||
Cash and cash equivalents |
$ |
129,440 |
$ |
99,058 | |
Receivables: |
|||||
Oil and natural gas sales |
52,073 |
45,443 | |||
Joint interest |
19,366 |
19,754 | |||
Income taxes |
65,240 |
13,006 | |||
Total receivables |
136,679 |
78,203 | |||
Prepaid expenses and other assets |
20,470 |
13,419 | |||
Total current assets |
286,589 |
190,680 | |||
Property and equipment |
8,189,495 |
8,123,875 | |||
Less accumulated depreciation, depletion and amortization |
7,613,422 |
7,544,859 | |||
Net property and equipment |
576,073 |
579,016 | |||
Restricted deposits for asset retirement obligations |
26,072 |
25,394 | |||
Income tax receivables |
- |
52,097 | |||
Other assets |
69,418 |
60,393 | |||
Total assets |
$ |
958,152 |
$ |
907,580 | |
Liabilities and Shareholders' Deficit |
|||||
Current liabilities: |
|||||
Accounts payable |
$ |
46,464 |
$ |
83,665 | |
Undistributed oil and natural gas proceeds |
22,649 |
20,129 | |||
Asset retirement obligations |
27,923 |
23,613 | |||
Current maturities of long-term debt: |
|||||
Principal |
189,829 |
- | |||
Carrying value adjustments |
34,917 |
22,925 | |||
Total current maturities of long-term debt |
224,746 |
22,925 | |||
Accrued liabilities |
20,505 |
17,930 | |||
Total current liabilities |
342,287 |
168,262 | |||
Long-term debt: |
|||||
Principal |
713,365 |
889,790 | |||
Carrying value adjustments |
47,605 |
79,337 | |||
Long-term debt, less current portion - carrying value |
760,970 |
969,127 | |||
Asset retirement obligations, less current portion |
289,297 |
276,833 | |||
Other liabilities |
73,007 |
66,866 | |||
Commitments and contingencies |
- |
- | |||
Shareholders' deficit: |
|||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 142,022,971 issued and 139,153,798 outstanding at June 30, 2018; 141,960,462 issued and 139,091,289 outstanding at December 31, 2017 |
1 |
1 | |||
Additional paid-in capital |
548,196 |
545,820 | |||
Retained earnings (deficit) |
(1,031,439) |
(1,095,162) | |||
Treasury stock, at cost |
(24,167) |
(24,167) | |||
Total shareholders' deficit |
(507,409) |
(573,508) | |||
Total liabilities and shareholders' deficit |
$ |
958,152 |
$ |
907,580 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||
Condensed Consolidated Statements of Cash Flows | |||||
(Unaudited) | |||||
Six Months Ended | |||||
June 30, | |||||
2018 |
2017 | ||||
(In thousands) | |||||
Operating activities: |
|||||
Net Income |
$ |
63,723 |
$ |
57,614 | |
Adjustments to reconcile net income to net cash provided by operating activities: |
|||||
Depreciation, depletion, amortization and accretion |
77,838 |
80,354 | |||
Gain on exchange of debt |
- |
(7,811) | |||
Amortization of debt items and other items |
1,126 |
836 | |||
Share-based compensation |
2,434 |
3,466 | |||
Derivative (gain) loss |
6,219 |
(7,644) | |||
Cash receipts (payments) on derivative settlements, net |
(1,149) |
2,208 | |||
Deferred income taxes |
221 |
212 | |||
Changes in operating assets and liabilities: |
|||||
Oil and natural gas receivables |
(6,630) |
3,675 | |||
Joint interest receivables |
251 |
1,965 | |||
Insurance reimbursements |
- |
30,100 | |||
Income taxes |
(138) |
(16,960) | |||
Prepaid expenses and other assets |
(14,323) |
(3,575) | |||
Escrow deposit - Apache lawsuit |
- |
(49,500) | |||
Asset retirement obligation settlements |
(12,124) |
(36,021) | |||
Accounts payable, accrued liabilities and other |
(2,256) |
6,666 | |||
Net cash provided by operating activities |
115,192 |
65,585 | |||
Investing activities: |
|||||
Investment in oil and natural gas properties and equipment |
(31,803) |
(43,800) | |||
Changes in operating assets and liabilities associated with investing activities |
(29,330) |
(827) | |||
Acquisition of property interest |
(16,617) |
- | |||
Purchases of furniture, fixtures and other |
- |
(853) | |||
Net cash used in investing activities |
(77,750) |
(45,480) | |||
Financing activities: |
|||||
Payment of interest on 1.5 Lien Term Loan |
(4,114) |
(4,113) | |||
Payment of interest on 2nd Lien PIK Toggle Notes |
(2,920) |
(7,335) | |||
Payment of interest on 3rd Lien PIK Toggle Notes |
- |
(6,201) | |||
Other |
(26) |
(372) | |||
Net cash used in financing activities |
(7,060) |
(18,021) | |||
Increase in cash and cash equivalents |
30,382 |
2,084 | |||
Cash and cash equivalents, beginning of period |
99,058 |
70,236 | |||
Cash and cash equivalents, end of period |
$ |
129,440 |
$ |
72,320 |
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.
Three Months Ended |
Six Months Ended | ||||||||||
June 30, |
June 30, | ||||||||||
2018 |
2017 |
2018 |
2017 | ||||||||
(In thousands, except per share amounts) | |||||||||||
(Unaudited) | |||||||||||
Net income |
$ |
36,083 |
$ |
33,315 |
$ |
63,723 |
$ |
57,614 | |||
Unrealized commodity derivative (gain) loss |
5,070 |
(2,194) |
5,070 |
(5,436) | |||||||
Default in payment by joint interest partners |
201 |
270 |
543 |
475 | |||||||
Gain on exchange of debt |
- |
(8,056) |
- |
(7,811) | |||||||
Apache lawsuit |
- |
6,285 |
- |
6,285 | |||||||
EC 321 settlement |
- |
(1,109) |
- |
(1,109) | |||||||
Penalties, litigation and related interest |
579 |
1,289 |
579 |
1,820 | |||||||
Income tax adjustment for the items above |
(18) |
1,297 |
(19) |
2,328 | |||||||
Net income excluding special items |
$ |
41,915 |
$ |
31,097 |
$ |
69,896 |
$ |
54,166 | |||
Basic and diluted income per common share, excluding special items |
$ |
0.29 |
$ |
0.22 |
$ |
0.48 |
$ |
0.38 |
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.
Three Months Ended |
Six Months Ended | ||||||||||
June 30, |
June 30, | ||||||||||
2018 |
2017 |
2018 |
2017 | ||||||||
(In thousands) | |||||||||||
(Unaudited) | |||||||||||
Net income |
$ |
36,083 |
$ |
33,315 |
$ |
63,723 |
$ |
57,614 | |||
Income tax expense (benefit) |
112 |
(8,975) |
221 |
(16,563) | |||||||
Net interest expense |
12,272 |
11,429 |
23,262 |
22,718 | |||||||
Depreciation, depletion, amortization and accretion |
39,757 |
40,364 |
77,838 |
80,354 | |||||||
EBITDA |
88,224 |
76,133 |
165,044 |
144,123 | |||||||
Adjustments: |
|||||||||||
Unrealized commodity derivative (gain) loss |
5,070 |
(2,194) |
5,070 |
(5,436) | |||||||
Default in payment by joint interest partners |
201 |
270 |
543 |
475 | |||||||
Gain on exchange of debt |
- |
(8,056) |
- |
(7,811) | |||||||
Apache lawsuit |
- |
6,285 |
- |
6,285 | |||||||
EC 321 settlement |
- |
(1,109) |
- |
(1,109) | |||||||
Civil penalties and other litigation |
(194) |
1,289 |
(194) |
1,820 | |||||||
Adjusted EBITDA |
$ |
93,301 |
$ |
72,618 |
$ |
170,463 |
$ |
138,347 | |||
Adjusted EBITDA Margin |
62% |
59% |
60% |
56% |
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Investor Relations |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
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SOURCE W&T Offshore, Inc.
HOUSTON, May 2, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its first quarter 2018 operational and financial results and second quarter and revised full year 2018 production and expense guidance. Some of the key highlights for the first quarter included:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "We were pleased to close our unique JV Drilling Program with an investor group during the first quarter, which we expect to enhance our return on investment and improve our financial flexibility. Subsequent to the initial close, additional investors have made commitments to the JV Drilling Program and we are in discussions with a few other investors who have expressed interest in joining the JV Drilling Program. We have already taken advantage of the additional liquidity it provided by completing a highly accretive acquisition.
"Our purchase in April 2018 of Cobalt's interest in the high cash flow generating Heidelberg field is an example of the type of opportunities that can boost our ability to build cash. The JV Drilling Program also positions us to reduce our 2018 Capital Budget while participating in additional projects that we believe can create solid returns for shareholders.
"Our drilling performance in 2018 has gotten off to a good start with two high production rate wells recently being placed on production at our Mahogany and Virgo fields. We have three rigs currently drilling with one at Ewing Bank 910 as well as one at Mahogany and one at Virgo. These fields all have existing infrastructure to allow for quick cash flow generation.
"Combined with improved oil and NGL prices that are positively impacting our revenue, we are increasingly optimistic about our ability to manage our debt obligations and end the year with a much improved balance sheet. Our oil production for the balance of 2018 is now 75% hedged at a floor of almost $60.00 per barrel so we believe that helps to de-risk a good portion of our cash flow steam," concluded Mr. Krohn.
Production, Prices and Revenues: Production for the first quarter of 2018 was 3.3 million Boe compared to the first quarter 2017 of 3.8 million Boe. First quarter 2018 production was comprised of 1.6 million barrels of oil, 0.4 million barrels of NGLs and 8.5 billion cubic feet ("Bcf") of natural gas. Oil and NGLs production comprised 57.3% of total production in the first quarter of 2018 compared to 56.7% of total production in the first quarter of 2017. Production for the first quarter of 2018 was below the 2017 level partially due to well maintenance, weather, pipeline outages, and platform maintenance that collectively resulted in deferred production of approximately 4,200 Boe per day, compared to 1,800 Boe per day in the first quarter of 2017.
Our Ship Shoal 299 field, Ship Shoal 349 ("Mahogany") field and South Timbalier 314 field delivered the largest production increases compared to the 2017 first quarter because of our successful drilling and development (completion, recompletion and workover programs). These were offset by production decreases primarily due to deferred production and natural production declines.
For the first quarter of 2018 our realized crude oil sales price was $62.52 per barrel, our realized NGL sales price was $27.54 per barrel and our realized natural gas sales price was $3.03 per Mcf. The combined average realized sales price was $39.92 per Boe compared to $32.12 per Boe in the first quarter of 2017.
Revenues for the first quarter of 2018 increased 7.9% to $134.2 million compared to $124.4 million in the first quarter of 2017. The increase was due to a 24.3% increase in our realized commodity sales price, partially offset by lower production volumes. We sold 36,976 Boe per day at an average realized sales price of $39.92 per Boe compared to 42,712 Boe per day at an average realized sales price of $32.12 per Boe in the first quarter of 2017. Over 73% of the change in production volumes between periods is attributable to the production deferrals referred to above.
Lease Operating Expenses: Lease operating expense ("LOE"), which includes base lease operating expenses, insurance premiums, workovers and facilities maintenance, was $36.8 million in the first quarter of 2018 compared to $40.2 million in the first quarter of 2017. On a component basis, base lease operating expenses were $30.2 million, insurance premiums were $2.7 million, workovers were $2.4 million and facilities maintenance was $1.5 million. Base LOE was down $1.7 million from the first quarter of 2017 primarily due to lower costs at non-operated properties. Insurance premiums were up $0.7 million on better insurance coverage while workover expenses decreased $1.5 million and facilities maintenance decreased $0.9 million, reflecting lower activity at lower rates for goods and services.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for asset retirement obligations ("ARO"), was $11.44 per Boe for the first quarter of 2018 compared to $10.40 per Boe for the first quarter of 2017. On a nominal basis, DD&A was $38.1 million for the first quarter of 2018, which was down from $40.0 million in the first quarter of 2017.
General and Administrative Expenses ("G&A"): G&A was $15.0 million for the first quarter of 2018 compared to $13.3 million in the first quarter of 2017. The increase was primarily due to increases in incentive compensation in 2018 which is solely a function of substantially better financial performance, partially offset by reductions in legal costs.
Derivative (gain) loss: We had no derivative contracts in place during the first quarter of 2018. We recorded a gain of $4.0 million in the first quarter of 2017 associated with crude oil derivative contracts. During April 2018, we entered into four different commodity derivative contracts for crude oil for a total of 11,000 barrels per day through the end of 2018. We entered into swaps, costless collars and also purchased puts. A list of those derivative positions may be found on our website at www.wtoffshore.com in the investor relations section.
Interest expense: Interest expense was $11.3 million in the first quarter of 2018, flat with the first quarter of 2017.
Income Tax: We recorded income tax expense of $0.1 million in the first quarter of 2018 on pre-tax income of $27.7 million compared to an income tax benefit of $7.6 million on pre-tax income of $16.7 million in the first quarter of 2017. The income tax expense in the first quarter of 2018 represents interest on a tax position. Otherwise tax expense is zero in the quarter. Our current full-year forecast for 2018 has the benefit of a net operating loss for tax purposes so no current tax expense is recorded on positive earnings. Any deferred tax expense is offset by a reduction in the valuation allowance in both periods.
The balance sheet at March 31, 2018 reflects current income tax receivables of $65.1 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 first quarter of 2018 of $27.6 million, or $0.19 per common share. Excluding special items, our adjusted net income was $28.0 million, or $0.19 per share. For the first quarter of 2017 we reported net income of $24.3 million, or $0.17 per common share; excluding special items, adjusted net income for the first quarter of 2017 would have been $22.8 million, or $0.16 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 first three months of 2018 was $75.0 million which is $6.2 million below the first quarter of 2017. In the first quarter of 2017 the company collected $30.1 million from an insurance claim that was from the 2008 time frame. The first quarter of 2018 reflects advances from investors in the JV Drilling Program of $19.2 million. Excluding these one-time items, cash flow from operating activities in the 2018 period would have been higher on improved operating results. Cash flows from operating activities (before changes in working capital, an insurance reimbursement, escrow deposits, advances from investors in the JV Drilling Program and ARO settlements) were $67.5 million in the first three months of 2018 compared to $63.7 for the same period in 2017.
Adjusted EBITDA for the first quarter of 2018 was $77.2 million and our Adjusted EBITDA margin was 57.5% compared to Adjusted EBITDA of $65.2 million and an Adjusted EBITDA margin of 52.4% for the first 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 March 31, 2018, our total liquidity was $280.4 million, consisting of an unrestricted cash balance of $130.7 million and $149.7 million of availability under our $150 million revolving bank credit facility.
Revised 2018 Capital Expenditure Program: As previously reported, due to establishing the joint venture drilling program with private investors through a newly formed entity called Monza Energy LLC ("the JV Drilling Program"), the Company has revised its 2018 capital expenditure program to $75 million from $130 million. These estimates do not include acquisitions. The $75 million capital budget is net of approximately $20 million in reimbursements for capital expenditures incurred by the Company for the wells included in the JV Drilling Program before the closing date.
The Company's 2018 capital expenditure program now includes participation in 11 wells, seven of which are included in the 2018 JV Drilling Program. The Company's drilling opportunities at Virgo continue to expand and we may have additional wells to add to the JV Drilling Program at this field. Having just concluded completion operations on the successful VK823 A-10 ST well, the platform rig has begun drilling operations on the VK823 A-12 well.
Other projects for 2018 that were previously announced include two more wells at the Mahogany field, the SS 359 A-5 ST2 development well (which is part of the JV Drilling Program) and the SS 349 A-19, (not part of the JV Drilling Program).
Two previously announced wells included in the 2018 JV Drilling Program are in our Ewing Bank 910 field. These wells, the South Timbalier 311 A-2 and A-3 wells, are both low-risk, high-return exploration opportunities with multiple stacked pay sands and, assuming success, can be brought on line quickly via existing infrastructure and pipelines. The 2018 capital expenditure program will have a very small interest in one well to be drilled at Mississippi Canyon 194, which is a change from a small interest in four wells originally planned there for 2018.
Additionally, we estimate we will spend approximately $31.6 million on plugging and abandonment activities in 2018.
Capital Expenditures: Our capital expenditures for oil and gas properties on an accrual basis for the first three months of 2018 were $21.1 million compared to $23.3 million for the 2017 period. The 2018 period reflects a net reimbursement from Monza of $20 million referred to above. In the first quarter of 2018 we completed two wells -- the A-17 well at Mahogany, which began producing during March 2018, and the Viosca Knoll 823 ("Virgo") A-10 ST1 well, which began production during April 2018. The Virgo A-10 ST well is now part of the JV Drilling Program.
Heidelberg Field: In addition to the capital expenditure budget of $75 million, in April 2018, the Company closed on the previously announced acquisition of a 9.375% working interest in the Heidelberg field from Cobalt International Energy. The gross purchase price was $31.1 million and the effective date was January 1, 2018. As previously disclosed, February's gross production from the field was 33,513 barrels of oil per day and 16,705 Mcf per day or 36,300 Boe per day. W&T's net benefit from the production from the field was 2,749 barrels of oil per day and 1.4 MMcf per day in February 2018 or almost 3,000 barrels of oil equivalent per day from 5 wells. Cash flow generated by the acquired interest between the effective date of January 1, 2018 and the closing date of April 5, 2018, serves to reduce the gross purchase price disclosed above.
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): The SS349 A-17 (not in JV Drilling Program) well that found a previously undiscovered deeper sand ('V' sand) and extended the known limits of one of the field pay sands seen in earlier wells, came on line towards the end of March. It is producing at an intentionally restricted test rate of approximately 1,925 Boe per day (82% oil). The rig is now drilling the SS349 A-5 ST well (in JV Drilling Program) targeting the 'Q' and 'P' sands. Please note that the A-5ST well will be the only well in our JV Drilling Program in this field. We expect to drill the SS 359 A-19 well (not in the JV Drilling Program) in the second half of 2018.
Viosca Knoll 823 "Virgo" (operated, shelf, in JV Drilling Program): In the first quarter of 2018, we successfully drilled the first well in a multi-well deepwater development program at our Virgo field. The VK822 A-10 ST well encountered 113 feet of high liquids condensate pay and due to the presence of infrastructure and our Virgo production platform, the well was put on-line quickly and achieved first production in mid-April. It is currently producing at a test rate of 1,250 Boe per day. The Company's drilling inventory at Virgo continues to expand and we now plan to include additional wells in the drilling program from this field. We have recently commenced drilling operations on the VK779 A-12 well (that is in block VK779), which is structurally higher and up dip to another well that has logged pay in a principal target sand.
Ewing Bank 910 Field Area (deepwater, in JV Drilling Program): Two new drill wells are planned in our Ewing Bank 910 field area, which are the South Timbalier 311 A-2 and A-3 wells. The rig has concluded mobilizing to the South Timbalier 311 Platform to begin drilling the A-2 well and just recently spud the well. Following the A-2 well operations, the rig is expected to then drill the 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 first quarter of 2018 we performed three recompletions that added approximately 1,190 Boe per day of initial production and four workovers that added approximately 570 Boe per day of initial production.
Second Quarter and Full Year 2018 Production and Expense Guidance
Our guidance for the second 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".
Second Quarter |
Prior Full Year |
Revised Full Year | ||
Production |
2018 |
2018 |
2018 | |
Oil and NGL's (MMBbls) |
2.0 - 2.2 |
7.5 - 8.3 |
7.8 - 8.6 | |
Natural Gas (Bcf) |
8.1 - 9.0 |
31.7 - 35.1 |
32.2 - 35.6 | |
Total (Bcfe) |
19.8 - 21.9 |
76.8 - 84.8 |
79.0 - 87.4 | |
Total (MMBoe) |
3.3 - 3.6 |
12.8 - 14.1 |
13.2 - 14.6 | |
Operating Expenses |
Second Quarter |
Prior Full Year |
Revised Full Year | |
($ in millions) |
2018 |
2018 |
2018 | |
Lease operating expenses |
$45 - $50 |
$154 - $170 |
$159 - $176 | |
Gathering, transportation & |
||||
production taxes |
$5 - $6 |
$23 -$26 |
$23 - $26 | |
General and administrative |
$14 - $16 |
$55 - $61 |
$56 - $62 | |
Income tax rate benefit |
0.0% |
0% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, May 3, 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 May 10, 2018, and may be accessed by calling 201-612-7415 and using the passcode 13678609#.
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 49 producing fields in federal and state waters and has under lease approximately 700,000 gross acres, including approximately 470,000 gross acres on the Gulf of Mexico Shelf and approximately 230,000 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 | |||||||
Condensed Consolidated Statements of Income (Loss) | |||||||
(Unaudited) | |||||||
Three Months Ended | |||||||
March 31, | |||||||
2018 |
2017 | ||||||
(In thousands, except per share data) | |||||||
Revenues: |
|||||||
Oil |
97,306 |
84,971 | |||||
NGLs |
9,660 |
8,742 | |||||
Natural gas |
25,867 |
29,758 | |||||
Other |
1,380 |
922 | |||||
Total revenues |
$ |
134,213 |
$ |
124,393 | |||
Operating costs and expenses: |
|||||||
Lease operating expenses |
36,843 |
40,164 | |||||
Gathering, transportation costs and production taxes |
5,512 |
6,724 | |||||
Depreciation, depletion, amortization and accretion |
38,081 |
39,990 | |||||
General and administrative expenses |
15,038 |
13,274 | |||||
Derivative gain |
- |
(3,955) | |||||
Total costs and expenses |
95,474 |
96,197 | |||||
Operating income |
38,739 |
28,196 | |||||
Interest expense |
11,323 |
11,294 | |||||
Other (income) expense, net |
(333) |
191 | |||||
Income before income tax expense (benefit) |
27,749 |
16,711 | |||||
Income tax expense (benefit) |
109 |
(7,588) | |||||
Net income |
$ |
27,640 |
$ |
24,299 | |||
Basic and diluted earnings per common share |
$ |
0.19 |
$ |
0.17 | |||
Weighted average common shares outstanding |
138,845 |
137,513 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Three Months Ended |
||||||||||||
March 31, |
Variance | |||||||||||
2018 |
2017 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
1,557 |
1,805 |
(248) |
-13.7% | ||||||||
NGL (MBbls) |
351 |
374 |
(23) |
-6.1% | ||||||||
Oil and NGLs (MBbls) |
1,907 |
2,180 |
(273) |
-12.5% | ||||||||
Natural gas (MMcf) |
8,523 |
9,985 |
(1,462) |
-14.6% | ||||||||
Total oil and natural gas (MBoe) (1) |
3,328 |
3,844 |
(516) |
-13.4% | ||||||||
Total oil and natural gas (MMcfe) (1) |
19,967 |
23,065 |
(3,098) |
-13.4% | ||||||||
Average daily equivalent sales (Boe/d) |
37.0 |
42.7 |
(5.7) |
-13.4% | ||||||||
Average daily equivalent sales (MMcfe/d) |
221.9 |
256.3 |
(34.4) |
-13.4% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
62.52 |
$ |
47.06 |
$ |
15.46 |
32.9% | |||||
NGLs ($/Bbl) |
27.54 |
23.34 |
4.20 |
18.0% | ||||||||
Oil and NGLs ($/Bbl) |
56.08 |
42.99 |
13.09 |
30.4% | ||||||||
Natural gas ($/Mcf) |
3.03 |
2.98 |
0.05 |
1.7% | ||||||||
Barrel of oil equivalent ($/Boe) |
39.92 |
32.12 |
7.80 |
24.3% | ||||||||
Natural gas equivalent ($/Mcfe) |
6.65 |
5.35 |
1.30 |
24.3% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
11.07 |
$ |
10.45 |
$ |
0.62 |
5.9% | |||||
Gathering and transportation costs and production taxes |
1.66 |
1.75 |
(0.09) |
-5.1% | ||||||||
Depreciation, depletion, amortization and accretion |
11.44 |
10.40 |
1.04 |
10.0% | ||||||||
General and administrative expenses |
4.52 |
3.45 |
1.07 |
31.0% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.85 |
$ |
1.74 |
$ |
0.11 |
6.3% | |||||
Gathering and transportation costs and production taxes |
0.28 |
0.29 |
(0.01) |
-3.4% | ||||||||
Depreciation, depletion, amortization and accretion |
1.91 |
1.73 |
0.18 |
10.4% | ||||||||
General and administrative expenses |
0.75 |
0.58 |
0.17 |
29.3% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly.
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data.
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Balance Sheets | |||||||
(Unaudited) | |||||||
March 31, |
December 31, | ||||||
2018 |
2017 | ||||||
(In thousands, except | |||||||
share data) | |||||||
Assets |
|||||||
Current assets: |
|||||||
Cash and cash equivalents |
$ |
130,711 |
$ |
99,058 | |||
Receivables: |
|||||||
Oil and natural gas sales |
44,942 |
45,443 | |||||
Joint interest |
17,835 |
19,754 | |||||
Income taxes |
65,103 |
13,006 | |||||
Total receivables |
127,880 |
78,203 | |||||
Prepaid expenses and other assets |
20,197 |
13,419 | |||||
Total current assets |
278,788 |
190,680 | |||||
Property and equipment |
8,151,755 |
8,123,875 | |||||
Less accumulated depreciation, depletion and amortization |
7,578,403 |
7,544,859 | |||||
Net property and equipment |
573,352 |
579,016 | |||||
Restricted deposits for asset retirement obligations |
25,622 |
25,394 | |||||
Income tax receivables |
- |
52,097 | |||||
Other assets |
64,414 |
60,393 | |||||
Total assets |
$ |
942,176 |
$ |
907,580 | |||
Liabilities and Shareholders' Deficit |
|||||||
Current liabilities: |
|||||||
Accounts payable |
$ |
77,444 |
$ |
83,665 | |||
Undistributed oil and natural gas proceeds |
22,273 |
20,129 | |||||
Asset retirement obligations |
25,748 |
23,613 | |||||
Long-term debt |
22,858 |
22,925 | |||||
Accrued liabilities |
23,293 |
17,930 | |||||
Total current liabilities |
171,616 |
168,262 | |||||
Long-term debt: |
|||||||
Principal |
889,790 |
889,790 | |||||
Carrying value adjustments |
77,691 |
79,337 | |||||
Long-term debt, less current portion - carrying value |
967,481 |
969,127 | |||||
Asset retirement obligations, less current portion |
280,735 |
276,833 | |||||
Other liabilities |
66,993 |
66,866 | |||||
Commitments and contingencies |
- |
- | |||||
Shareholders' deficit: |
|||||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 141,960,462 issued and 139,091,289 outstanding at March 31, 2018 and December 31, 2017 |
1 |
1 | |||||
Additional paid-in capital |
547,039 |
545,820 | |||||
Retained earnings (deficit) |
(1,067,522) |
(1,095,162) | |||||
Treasury stock, at cost |
(24,167) |
(24,167) | |||||
Total shareholders' deficit |
(544,649) |
(573,508) | |||||
Total liabilities and shareholders' deficit |
$ |
942,176 |
$ |
907,580 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||
Condensed Consolidated Statements of Cash Flows | ||||||||
(Unaudited) | ||||||||
Three Months Ended |
||||||||
March 31, |
||||||||
2018 |
2017 |
|||||||
(In thousands) |
||||||||
Operating activities: |
||||||||
Net Income |
$ |
27,640 |
$ |
24,299 |
||||
Adjustments to reconcile net income to net cash provided by operating activities: |
||||||||
Depreciation, depletion, amortization and accretion |
38,081 |
39,990 |
||||||
Amortization of debt items |
466 |
412 |
||||||
Share-based compensation |
1,219 |
1,928 |
||||||
Derivative gain |
- |
(3,955) |
||||||
Cash receipts on derivative settlements, net |
- |
713 |
||||||
Deferred income taxes |
109 |
105 |
||||||
Changes in operating assets and liabilities: |
||||||||
Oil and natural gas receivables |
501 |
(1,882) |
||||||
Joint interest receivables |
1,919 |
5,042 |
||||||
Insurance reimbursements |
- |
30,100 |
||||||
Prepaid expenses and other assets |
(6,391) |
(7,972) |
||||||
Asset retirement obligation settlements |
(7,022) |
(14,499) |
||||||
Cash advances from JV Partners |
19,147 |
(2,531) |
||||||
Accounts payable, accrued liabilities and other |
(688) |
9,433 |
||||||
Net cash provided by operating activities |
74,981 |
81,183 |
||||||
Investing activities: |
||||||||
Investment in oil and natural gas properties and equipment |
(21,117) |
(23,338) |
||||||
Changes in operating assets and liabilities associated with investing activities |
(17,154) |
1,168 |
||||||
Deposit for acquisition |
(3,000) |
- |
||||||
Purchases of furniture, fixtures and other |
- |
(853) |
||||||
Net cash used in investing activities |
(41,271) |
(23,023) |
||||||
Financing activities: |
||||||||
Payment of interest on 1.5 Lien Term Loan |
(2,057) |
(2,056) |
||||||
Other |
- |
(245) |
||||||
Net cash used in financing activities |
(2,057) |
(2,301) |
||||||
Increase in cash and cash equivalents |
31,653 |
55,859 |
||||||
Cash and cash equivalents, beginning of period |
99,058 |
70,236 |
||||||
Cash and cash equivalents, end of period |
$ |
130,711 |
$ |
126,095 |
||||
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), default in payment by joint interest partners, costs related to the exchange of debt 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.
Three Months Ended | |||||||||
March 31, | |||||||||
2018 |
2017 | ||||||||
(In thousands, except per share amounts) | |||||||||
(Unaudited) | |||||||||
Net income |
$ |
27,640 |
$ |
24,299 | |||||
Unrealized commodity derivative gain |
- |
(3,242) | |||||||
Default in payment by joint interest partners |
342 |
205 | |||||||
Costs related to the exchange of debt |
- |
245 | |||||||
Income tax adjustment for the items above … |
- |
1,268 | |||||||
Net income excluding special items |
$ |
27,982 |
$ |
22,775 | |||||
Basic and diluted income per common share, excluding special items |
$ |
0.19 |
$ |
0.16 |
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, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative (gain), default in payment by joint interest partners, and costs related to the exchange of debt. 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 (loss) to EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Three Months Ended | ||||||||||
March 31, | ||||||||||
2018 |
2017 | |||||||||
(In thousands) | ||||||||||
(Unaudited) | ||||||||||
Net income |
$ |
27,640 |
$ |
24,299 | ||||||
Income tax expense (benefit) |
109 |
(7,588) | ||||||||
Net interest expense |
10,990 |
11,289 | ||||||||
Depreciation, depletion, amortization and accretion |
38,081 |
39,990 | ||||||||
EBITDA |
76,820 |
67,990 | ||||||||
Adjustments: |
||||||||||
Unrealized commodity derivative gain |
- |
(3,242) | ||||||||
Default in payment by joint interest partners |
342 |
205 | ||||||||
Costs related to the exchange of debt |
- |
245 | ||||||||
Adjusted EBITDA |
$ |
77,162 |
$ |
65,198 | ||||||
Adjusted EBITDA Margin |
57% |
52% |
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Investor Relations |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-first-quarter-2018-operational-and-financial-results-revised-2018-capital-expenditure-program-and-2018-guidance-300641505.html
SOURCE W&T Offshore, Inc.
HOUSTON, April 17, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its first quarter 2018 financial and operational results after the market closes on Wednesday, May 2, 2018. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Thursday, May 3 at 10:00 a.m. Eastern Time (9:00 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through May 10, 2018 by dialing 1-201-612-7415 and using the passcode 13678609. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
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 approximately 49 producing fields in federal and state waters and has under lease approximately 700,000 gross acres, including approximately 470,000 gross acres on the Gulf of Mexico Shelf and approximately 230,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons | |
Dennard Lascar Investor Relations |
SVP & CFO | ||
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | ||
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-first-quarter-2018-financial-and-operational-results-release-and-conference-call-schedule-300631523.html
SOURCE W&T Offshore, Inc.
HOUSTON, Feb. 28, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its fourth quarter 2017 operational and financial results. The Company also reported its year-end 2017 proved reserves with a 100% reserve replacement rate and provided its 2018 capital expenditure program, and first quarter and full year 2018 production and expense guidance. Some of the key highlights for the fourth quarter and full year 2017 included:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "Our successful drilling program, combined with the effective development and excellent performance of some of our major fields, allowed us to replace just over 100% of our production on capital expenditures of only $130 million for the year, which we funded with cash on hand and cash flow from operations, i.e., within cash flow. Production was down about 5% compared to 2016, primarily due to pipeline and platform outages along with tropical storm downtime.
"One of our objectives over the last few years following the industry downturn has been to build our cash position while maintaining steady production and proved reserve levels. In 2017, we successfully met those goals while increasing our cash balance by $28.8 million to $99.1 million. We expect to see further improvement in our 2018 cash flow as well as increases in our cash balances as our unhedged production benefits from higher oil prices and our 2018 capital plan remains a modest $130 million.
"Additionally, we expect to receive $65.1 million of tax refunds in 2018, although a portion of it could occur later, related to plugging and abandonment activities that allow us to capture net operating loss carrybacks. By ending 2017 with a strong cash balance and building cash throughout 2018, we expect to be in a good position to be able to either fund our upcoming 2019 debt maturities during 2018 or refinance, or a combination of both, as appropriate.
"Our capital expenditure program for 2018 is composed of select lower-risk, high-return, oil-focused projects combined with higher risk, higher return oil focused wells that, assuming success, would be placed on production fairly quickly. Our inventory of high quality exploration drilling and field extension projects in the Gulf of Mexico is based on advanced seismic and processing which provide further insight into some of our key fields.
"To provide additional financial flexibility, as we have previously reported, throughout 2017 and now into 2018 we have been working to establish a drilling joint venture with private investors. We are in the final stages of establishing such a drilling joint venture that will allow us to drill and exploit assets on a promoted basis and with reduced capital outlay. We have completed negotiations with an initial group of investors but are subject to funding at an initial closing expected to occur by mid-March. More investors may join the joint venture before or after the initial closing.
"It's important to note that establishing an investment vehicle with outside parties that will allow us to drill our wells on a promoted basis, will enable our 2018 capital spending requirements, as outlined in this press release, to be much lower. Once all conditions to the initial closing of this joint venture are met we will announce final terms and revise our 2018 capital budget. Additionally, this joint venture could position us in the future to participate in high quality prospects that we may not otherwise be able to participate in," concluded Mr. Krohn.
It is expected that entities owned and controlled by Tracy W. Krohn, Chairman and Chief Executive Officer of the Company, and his family will invest on the same terms as are negotiated with unaffiliated investors to acquire an approximate 4% interest in the drilling joint venture.
Production, Prices and Revenues: Production for the fourth quarter of 2017 was 3.5 million Boe compared to the fourth quarter 2016 of 3.7 million Boe. Fourth quarter 2017 production was comprised of 1.6 million barrels of oil, 0.4 million barrels of NGLs and 8.7 billion cubic feet ("Bcf") of natural gas. Oil and NGLs production comprised 58% of total production in the fourth quarter of 2017 compared to 55% of total production in the fourth quarter of 2016. Production for the fourth quarter of 2017 was primarily impacted by well maintenance, weather, pipeline outages, and platform maintenance that collectively resulted in deferred production of almost 6,100 Boe per day.
For the full year 2017, production was 14.6 million Boe, compared to 15.4 million Boe in 2016. Total 2017 production was comprised of 7.1 million barrels of oil, 1.4 million barrels of NGLs and 36.8 Bcf of natural gas. For the full year, production was impacted by well maintenance, weather, pipeline outages, and platform maintenance that collectively resulted in deferred production of over 4,600 Boe per day.
The Mahogany, Ewing Bank 910, and Virgo fields delivered the largest production increases for the year 2017 compared to the 2016 period because of our successful drilling, completion, recompletion and workover programs.
For the fourth quarter of 2017 our realized crude oil sales price was $55.83 per barrel, our realized NGL sales price was $27.55 per barrel and our realized natural gas sales price was $2.95 per Mcf. The combined average realized sales price was $36.79 per Boe compared to $30.83 per Boe in the fourth quarter of 2016. For the full year of 2017 our realized sales price for crude oil was $48.13 per barrel (representing an increase of 28.9% over 2016), our NGL realized sales price was $23.35 per barrel (representing an increase of 36.2% over 2016) and our realized sales price for natural gas was $2.96 per Mcf (representing an increase of 17.0% over 2016). Our combined realized sales price was $33.02 per Boe compared to $25.76 per Boe for the full year 2016, representing an increase of 28.2%. During the last two months of 2017 our crude oil price differentials became positive as the Brent/WTI differentials widened and the light/heavy crude differentials narrowed. We believe this is primarily attributable to the turmoil in Venezuela that has led to reduced imports of sour and heavy crude oil into the United States.
Revenues for the fourth quarter of 2017 increased 12.1% to $129.1 million compared to $115.2 million in the fourth quarter of 2016. The increase in revenues was due to a 19.3% increase in our realized commodity price, offset by production volumes that were adversely impacted by 6,100 Boe per day of deferred production as previously mentioned. We sold 37,526 Boe per day at an average realized sales price of $36.79 per Boe compared to 40,254 Boe per day as compared to an average realized sales price of $30.83 per Boe in the fourth quarter of 2016.
For the year 2017, revenues were $487.1 million, up 22% or $87.1 million over the 2016 period. Revenues were up $100.8 million due to higher prices, partially offset by lower production volumes.
Lease Operating Expenses: Lease operating expense ("LOE"), which includes base lease operating expenses, insurance premiums, workovers and facilities maintenance, was $36.9 million in the fourth quarter of 2017 compared to $33.8 million in the fourth quarter of 2016. On a component basis, base lease operating expenses were $30.4 million, insurance premiums were $2.6 million, workovers were $0.3 million and facilities maintenance was $3.6 million. Base LOE was up $2.2 million over the fourth quarter of 2016 with higher incentive compensation accruals due to significantly better financial performance and due to increased activities at three of our fields. Insurance premiums were up $0.6 million while workover expenses decreased $1.9 million due to the 2016 period reflecting higher activity. Facilities maintenance increased $1.0 million due to increased activity at several fields but primarily associated with work at Matterhorn. Finally, the 2016 period reflected a portion of an insurance reimbursement related to settlement of a Hurricane Ike claim.
For the year 2017, LOE was $143.7 million which was $8.7 million below the 2016 period due to lower base LOE and lower insurance premiums. Base LOE was lower by $10.5 million on a decrease in the cost of goods and services resulting from structural operational changes, reduced vendor pricing in the Gulf of Mexico and higher production handling fees (cost offsets) at certain fields.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for asset retirement obligations ("ARO"), was $11.25 per Boe for the fourth quarter of 2017 compared to $10.50 per Boe for the fourth quarter of 2016. On a nominal basis, DD&A was $38.8 million for the fourth quarter of 2017 which was flat with the fourth quarter of 2016. For the year 2017, DD&A on a nominal basis was $155.7 million which is down $55.9 million from the 2016 period primarily because of the ceiling test write-downs of $279.1 million in the 2016 period which lowered the full cost pool subject to depletion.
General and Administrative Expenses ("G&A"): G&A was $14.4 million for the fourth quarter of 2017 and flat with the fourth quarter of 2016. Decreases in medical claims and lower legal costs were entirely offset by higher professional services associated with reservoir engineering and higher surety bond premiums. G&A for the full year 2017 was also flat compared to the full year of 2016.
Derivative (gain) loss: Fourth quarter of 2017 reflects a loss of $0.6 million associated with crude oil derivative contracts compared to a loss of less than $0.1 million in the fourth quarter of 2016. For the year 2017, the Company realized a gain of $4.2 million compared to a loss of $2.9 million in the 2016 period.
Interest expense: Interest expense was $11.6 million in the fourth quarter of 2017, flat with the fourth quarter of 2016. For the year 2017, interest expense was $45.8 million which represents a decrease of $46.4 million from the 2016 period due to the Exchange Transaction that was completed on September 7, 2016, when we exchanged $710.2 million of our Unsecured Senior Notes for $301.8 million of new secured notes and 60.4 million shares of common stock, and at the same time, closed on a $75.0 million, 1.5 Lien Term Loan. Interest expense was also lower because we had no borrowings on the $150 million revolving bank credit facility during 2017 compared to borrowings averaging approximately $150.0 million from the beginning of January 2016 until we closed on the Exchange Transaction.
Income Tax: We recorded an income tax benefit of $1.5 million in the fourth quarter of 2017 on pre-tax income of $21.9 million compared to income tax expense of $1.0 million on pre-tax income of $17.5 million in the fourth quarter of 2016. Our annualized effective tax rate for both periods was not meaningful. The income tax benefit in the 2017 period relates to NOL carryback claims made pursuant to IRC Section 172(f) (related to rules for "specified liability losses"-, which permit certain platform dismantlement, well abandonment and site clearance costs to be carried back 10 years. The full year 2017 reflects a tax benefit of $12.6 million on pre-tax income of $67.1 million. The benefit for 2017 reflects an estimated tax refund of $13.0 million that we expect to receive sometime in the second or third quarter of 2018 that relates to our specified liability loss carryback for plugging and abandonment expenditures made in 2017.
As of December 31, 2017, the balance sheet reflects current income tax receivables of $13.0 million and non-current income tax receivables of $52.1 million. The non-current income tax receivable relates to our NOL claims for the years 2012, 2013 and 2014 that were carried back to prior years. These various carryback claims are made pursuant to IRC Section 172(f) described above.
Tax Cuts and Jobs Act ("TCJA"): The TCJA of 2017 modified certain U.S. Federal income tax provisions available to corporations. Along with lowering the corporate income tax rate, the TCJA changed certain income tax rules and deductions including cost recovery, limits on the deductions of interest expense, the elimination of the deduction from domestic production activities and utilization of net operating losses. Under the TCJA effective in 2018, the rules related to specified liability losses have been eliminated and additional claims will not be allowed in 2018 and forward. The TCJA does not affect the NOL carryback claims that we previously filed and are referenced above, nor does the TCJA affect the review process for such claims. As a result of TCJA, our net deferred tax assets and associated valuation allowance were provisionally adjusted downwards by $105.9 million as of December 31, 2017. No other changes were needed to either the income statement or balance sheet as a result of the TCJA.
Net Income (Loss) & Earnings Per Share: We reported net income for the fourth quarter of 2017 of $23.4 million or $0.16 per common share. Excluding special items, our adjusted net income was $24.2 million and our earnings were $0.17 per share. For the fourth quarter of 2016 we reported net income of $16.5 million, or $0.12 per common share; excluding special items, adjusted net income for the fourth quarter of 2016 would have been $7.7 million, or $0.06 per share. (See the "Reconciliation of Net Income (Loss) to Net Income (Loss) 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 year 2017 was $159.4 million which represents an increase of $145.2 million over the year 2016. Cash flows from operating activities, (before changes in working capital, insurance reimbursements, escrow deposits and ARO settlements), were $235.6 million in 2017 compared to $103.1 million in 2016.
The increase in cash flows in 2017 was primarily due to higher realized prices for all our commodities – crude oil, NGLs and natural gas, lower operating expenses and lower interest payments, primarily offset by deferred production volumes. Our combined average realized sales price per Boe increased 28.2%, which increased revenues by $100.8 million. However, production volumes decreased on a Boe basis by 5.2%, which lowered revenues by $15.4 million. Operating expenses decreased by $11.3 million and interest expense decreased $46.4 million. Interest payments related to the debt that was part of the Exchange Transaction are reported as a part of "cash flows from financing activities". Other items affecting operating cash flows for 2017 were ARO settlements of $72.4 million and an escrow deposit of $49.5 million to secure the appeal of the Apache lawsuit, partially offset by insurance reimbursements of $31.7 million.
Adjusted EBITDA for the fourth quarter of 2017 was $72.9 million and our Adjusted EBITDA margin was 56%. Adjusted EBITDA for the year 2017 was $268.4 million, up from $179.1 million in the 2016 period. Our Adjusted EBITDA margin was 55% for the year 2017 compared to 45% for the 2016 period.
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 December 31, 2017, our total liquidity was $248.8 million, consisting of an unrestricted cash balance of $99.1 million and $149.7 million of availability under our $150 million revolving bank credit facility.
Capital Expenditures: Our capital expenditures for oil and gas properties on an accrual basis for the year 2017 were $130.0 million compared to $48.6 million for the 2016 period ($106.2 million in the 2017 period on a cash basis compared to $83.8 million for the 2016 period). In 2017 about 44% of our capital expenditures were dedicated to four drill wells at our Mahogany field while the remainder was dedicated to new exploration wells at Ship Shoal 300, Main Pass 286, and an unsuccessful well at South Timbalier 224. We also performed recompletions at Main Pass 69, High Island 22, Main Pass 108 and a number of other fields. The remaining expenditures were associated with development activities and seismic.
2018 Capital Expenditure Program: Currently, we have established a 2018 capital program of $130.0 million that includes 12 wells to be drilled (four of which were started in 2017, one of which has been abandoned as a dry hole), of which seven are deepwater wells and five are shelf wells. Six of the deepwater wells and four of the shelf wells are exploratory. The budget also includes 12 recompletes that are expected to cost approximately $7.5 million. Approximately $35 million of the budget is related to projects that commenced in 2017 with the remainder dedicated to new projects in 2018. Additionally, we estimate we will spend approximately $24 million on plugging and abandonment activities in 2018.
We expect that this budget may result in a slight decrease in our 2018 production compared to 2017. Our estimates of production for 2018 are a function of the timing of the expenditures and the success of the wells and our other work programs. Our estimates do not yet reflect the full impact of our proposed drilling joint venture. Nor do these estimates reflect what we believe are viable acquisition opportunities that can increase both production and reserves. We continue to evaluate these opportunities and are confident that we can execute on them as they arise.
Projects included in the 2018 capital spending plan that are already under way include the completion of Ship Shoal 349 (Mahogany) A-17, a well that has found two new objectives in two new sands; development of the Main Pass 286 #1, a successful 2017 exploration well; and Viosca Knoll 823 (Virgo) A-10 ST, a deepwater development well that is up-dip to known pay.
New projects in our 2018 capital program include two more wells at the Mahogany field, the SS 349 A-5 ST2, a low-cost side track well targeting the "P" sand; and the SS 359 A-20, an exploration/exploitation well. Two wells are also planned at Ewing Bank 910 field, the ST 311 A-2 and A-3 wells, both of which are low-risk, high-return exploration opportunities with multiple stacked pay sands. If successful, all of these wells can be brought on line quickly via existing infrastructure and pipelines. Additionally, we expect the recompletions that are planned will provide low-cost production additions.
Virtually all of these projects meet our objectives of having a very high probability of success, expected high rates of return and short-term payout, and the ability to boost production levels in 2018 or early 2019.
OPERATIONS UPDATE
Ship Shoal 349 "Mahogany" (100% WI, operated, shelf): We recently completed the drilling of the A-17 well that found a previously undiscovered deeper sand (V-Sand) and extended the known limits of one of the field pay sands seen in earlier wells, resulting in proved reserve additions with significant upside. The A-17 well will initially be completed in the newly discovered sands with production expected to commence late in the first quarter. Following the A-17 well, we will begin drilling the A-5 ST well targeting the 'Q' and 'P' sands that were logged and evaluated in the A-18 well drilled in 2017. Workover and recompletion opportunities continue to exist at Mahogany and will be done as time and operating conditions permit. Mahogany production averaged over 6,900 Boe per day net to our interest in 2017.
Viosca Knoll 823 "Virgo": We recently mobilized a rig to our Virgo Platform to commence what we anticipate will be a multi-well deepwater drilling program. Our first well in the program, the A-10 ST well, targeted an up-dip attic position nearby to a logged well in some of the deep main field pays. The well recently reached total depth of 16,770 feet and logged a significant hydrocarbon column in our target objective. We are now moving into completion mode and will likely have the well on line during early second quarter. Following the completion of the A-10 ST, we expect to begin drilling the second well in our drilling program at Virgo. One attractive feature of this drilling program is our ability to achieve early cash flow from the wells due to the presence of infrastructure and our Virgo production platform. W&T Offshore, Inc. is the operator with an 80% working interest in the A-10 ST well. The co-owner is EnVen Energy Ventures, LLC, a wholly owned subsidiary of EnVen Energy Corporation, with 20% working interest.
Ewing Bank 910 (36% - 50% WI, operated, deepwater): Two wells are planned in our Ewing Bank 910 field, which are the South Timbalier 311 A-2 and A-3 wells. We anticipate beginning rig mobilization in the first quarter of 2018 with a likely spud date sometime in the second quarter of 2018. We believe both of these wells are low-risk exploration opportunities with multiple stacked pay sands. Assuming success, these wells can be brought on line quickly via existing infrastructure and pipelines.
Main Pass 286 (100% WI, operated, shelf): This well was drilled late in the fourth quarter of 2017 resulting in a new field discovery. We are evaluating our optimal development scenarios, which will likely include bringing the production back to a platform at MP 283 which is a nearby W&T owned facility. We expect to proceed with development later this year. Although dependent upon final project sanction and our development solution, we are expecting this discovery to achieve first production sometime during early 2019.
Well Recompletions and Workovers: During 2017, we performed 16 recompletions that added approximately 4,440 Boe per day of initial production and 11 workovers that added approximately 6,600 Boe per day of initial production. For 2018 we anticipate performing 12 recompletions for a cost of around $7.5 million that will lead to additional production.
Year-End 2017 Proved Reserves
The Company's year-end 2017 SEC proved reserves were 74.2 million Boe, or 445.3 Bcfe, with 57% comprised of liquids (46% crude oil and 11% NGLs) and 43% natural gas. The Company achieved a reserve replacement rate in excess of 100% for calendar year 2017. At year end, approximately 74% of our 2017 proved reserves were classified as proved developed producing, 10% as proved developed non-producing and 16% as proved undeveloped. This represents an increase 15.2% in our proved developed reserves over 2016.
Total production in 2017 of approximately 14.6 million Boe was more than offset by upward revisions to previous reserve estimates due to successful well performance in several key fields, as well as new extensions and discoveries. We also had favorable revisions due to an increase of $8.59 per barrel in crude prices and an increase of $0.50 per Mcf in natural gas prices. Total proved reserves at year-end 2016 were 74.0 million Boe, 55% of which were comprised of crude oil and NGLs.
The present value of our reported SEC proved reserves, discounted at 10% ("PV-10"), at such date was $992.9 million, up 32% from $754.9 million at the end of 2016. The standardized measure of future net cash flows of our SEC proved reserves was $740.6 million at December 31, 2017. The 2017 SEC PV-10 is based on an average crude oil price of $51.34 per barrel and average natural gas price of $2.98 per Mcf, both after adjustment for quality, transportation, fees, energy content, and regional price differentials. For purposes of calculating the SEC PV-10 for 2016, the average crude oil price was $42.75 per barrel and the average natural gas price was $2.48 per Mcf.
Summary Reconciliation W&T Offshore, Inc | |||||||||||
Oil |
NGL |
Gas |
Net |
Net |
|||||||
MBbls |
MBbls |
MMcf |
MMcfe |
MBoe |
PV-10 | ||||||
BALANCE, DECEMBER 31, 2016 |
32,886 |
8,150 |
197,798 |
444,011 |
74,002 |
$754,933 | |||||
REVISIONS OF PREVIOUS ESTIMATES |
3,045 |
545 |
15,561 |
37,100 |
6,183 |
||||||
REVISIONS DUE TO SEC BASE PRICE CHANGE |
1,457 |
229 |
10,182 |
20,297 |
3,383 |
||||||
EXTENSIONS, DISCOVERIES |
4,063 |
261 |
5,391 |
31,333 |
5,222 |
||||||
PURCHASES OF MINERALS IN PLACE |
0 |
0 |
0 |
0 |
0 |
||||||
SALES OF MINERALS IN PLACE |
0 |
0 |
0 |
0 |
0 |
||||||
PRODUCTION |
(7,064) |
(1,381) |
(36,754) |
(87,428) |
(14,571) |
||||||
BALANCE, DECEMBER 31, 2017 |
34,386 |
7,803 |
192,179 |
445,314 |
74,219 |
$992,858 |
(1) |
PV-10 for this presentation excludes any provision for asset retirement obligations or income taxes. |
(2) |
In accordance with guidelines established by the SEC, our estimated proved reserves as of December 31, 2017 were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average commodity price for each product, calculated as the unweighted arithmetic average of the price on the first day of each month for the year end December 31, 2017. The West Texas Intermediate spot price and the Henry Hub spot price were utilized as the referenced price and after adjusting for quality, transportation, fees, energy content and regional price differentials. In determining the estimated realized price for NGLs, a ratio was computed for each field of the NGLs realized price compared to the crude oil realized price. Then, this ratio was applied to the crude oil price using SEC guidance. Such prices were held constant throughout the estimated lives of the reserves. Future production and development costs are based on year-end costs with no escalations. |
(3) |
Standardized measure of future net cash flows of our SEC proved reserves was (i) $478 million at December 31, 2016, which excludes from PV-10 $ 277 million of discounted asset retirement obligations and no amount for discounted future income taxes and (ii) $ 741 million at December 31, 2017, which excludes from PV-10 $192 million of discounted asset retirement obligations and $60 million of discounted future income taxes. PV-10 for this presentation excludes any provision for asset retirement obligations or income taxes. |
For comparative purposes, utilizing the forward closing prices on the New York Mercantile Exchange (NYMEX) for crude oil and natural gas on December 29, 2017 (the last day of trading in 2017), totaled proved reserves would have been 74.3 million Boe, with a PV-10 value of $1.1 billion.
First Quarter and Full Year 2018 Production and Expense Guidance:
Our guidance for the first quarter and full year 2018 in the table below represents the Company's best estimate of the range of likely future results. Guidance could be affected by the factors described below in "Forward-Looking Statements" and our estimates do not yet reflect the full impact of our proposed drilling joint venture.
First Quarter |
Full Year | ||
Production |
2018 |
2018 | |
Oil and NGL's (MMBbls) |
1.8 - 2.0 |
7.5 - 8.3 | |
Natural Gas (Bcf) |
7.9 - 8.8 |
31.7 - 35.1 | |
Total (Bcfe) |
18.7 - 20.7 |
76.8 - 84.8 | |
Total (MMBoe) |
3.1 - 3.5 |
12.8 - 14.1 | |
Operating Expenses |
First Quarter |
Full Year | |
($ in millions) |
2018 |
2018 | |
Lease operating expenses |
$34 - $38 |
$154 - $170 | |
Gathering, transportation & |
|||
production taxes |
$5 - $6 |
$23 - $26 | |
General and administrative |
$13 - $14 |
$55 - $61 | |
Income tax rate benefit |
- |
0% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, March 1, 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 March 8, 2018, and may be accessed by calling 201-612-7415 and using the passcode 13676094#.
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 49 producing fields in federal and state waters and has under lease approximately 700,000 gross acres, including approximately 470,000 gross acres on the Gulf of Mexico Shelf and approximately 230,000 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, 2016 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Investor Relations |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||||||
Condensed Consolidated Statements of Income (Loss) | |||||||||||
(Unaudited) | |||||||||||
Three Months Ended |
Twelve Months Ended | ||||||||||
December 31, |
December 31, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
(In thousands, except per share data) | |||||||||||
Revenues |
$ |
129,099 |
$ |
115,213 |
$ |
487,096 |
$ |
399,986 | |||
Operating costs and expenses: |
|||||||||||
Lease operating expenses |
36,921 |
33,788 |
143,738 |
152,399 | |||||||
Gathering, transportation costs and production taxes |
5,242 |
6,788 |
22,181 |
24,817 | |||||||
Depreciation, depletion, amortization and accretion |
38,839 |
38,883 |
155,682 |
211,609 | |||||||
Ceiling test write-down of oil and natural gas properties |
- |
- |
- |
279,063 | |||||||
General and administrative expenses |
14,365 |
14,370 |
59,744 |
59,740 | |||||||
Derivative (gain) loss |
566 |
65 |
(4,199) |
2,926 | |||||||
Total costs and expenses |
95,933 |
93,894 |
377,146 |
730,554 | |||||||
Operating income (loss) |
33,166 |
21,319 |
109,950 |
(330,568) | |||||||
Interest expense, net of amounts capitalized |
11,552 |
11,511 |
45,836 |
92,271 | |||||||
Gain on exchange of debt |
- |
(37) |
7,811 |
123,923 | |||||||
Other (income) expense, net |
(261) |
(7,729) |
4,812 |
(6,520) | |||||||
Income (loss) before income tax expense (benefit) |
21,875 |
17,500 |
67,113 |
(292,396) | |||||||
Income tax expense (benefit) |
(1,490) |
1,017 |
(12,569) |
(43,376) | |||||||
Net income (loss) |
$ |
23,365 |
$ |
16,483 |
$ |
79,682 |
$ |
(249,020) | |||
Basic and diluted earnings (loss) per common share |
$ |
0.16 |
$ |
0.12 |
$ |
0.56 |
$ |
(2.60) | |||
Weighted average common shares outstanding |
137,826 |
137,031 |
137,617 |
95,644 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||
Condensed Operating Data | ||||||||||
(Unaudited) | ||||||||||
Three Months Ended |
||||||||||
December 31, |
Variance | |||||||||
2017 |
2016 |
Variance |
Percentage(2) | |||||||
Net sales volumes: |
||||||||||
Oil (MBbls) |
1,637 |
1,670 |
(33) |
-2.0% | ||||||
NGL (MBbls) |
358 |
361 |
(3) |
-0.8% | ||||||
Oil and NGLs (MBbls) |
1,994 |
2,031 |
(37) |
-1.8% | ||||||
Natural gas (MMcf) |
8,749 |
10,035 |
(1,286) |
-12.8% | ||||||
Total oil and natural gas (MBoe) (1) |
3,452 |
3,703 |
(251) |
-6.8% | ||||||
Total oil and natural gas (MMcfe) (1) |
20,714 |
22,220 |
(1,506) |
-6.8% | ||||||
Average daily equivalent sales (Boe/d) |
37.5 |
40.3 |
(2.7) |
-6.8% | ||||||
Average daily equivalent sales (MMcfe/d) |
225.2 |
241.5 |
(16.4) |
-6.8% | ||||||
Average realized sales prices: |
||||||||||
Oil ($/Bbl) |
$ |
55.83 |
$ |
45.10 |
$ |
10.73 |
23.8% | |||
NGLs ($/Bbl) |
27.55 |
21.37 |
6.18 |
28.9% | ||||||
Oil and NGLs ($/Bbl) |
50.76 |
40.87 |
9.89 |
24.2% | ||||||
Natural gas ($/Mcf) |
2.95 |
3.11 |
(0.16) |
-5.1% | ||||||
Barrel of oil equivalent ($/Boe) |
36.79 |
30.83 |
5.96 |
19.3% | ||||||
Natural gas equivalent ($/Mcfe) |
6.13 |
5.14 |
0.99 |
19.3% | ||||||
Average per Boe ($/Boe): |
||||||||||
Lease operating expenses |
$ |
10.69 |
$ |
9.12 |
$ |
1.57 |
17.2% | |||
Gathering and transportation costs and production taxes |
1.52 |
1.83 |
(0.31) |
-16.9% | ||||||
Depreciation, depletion, amortization and accretion |
11.25 |
10.50 |
0.75 |
7.1% | ||||||
General and administrative expenses |
4.16 |
3.88 |
0.28 |
7.2% | ||||||
Average per Mcfe ($/Mcfe): |
||||||||||
Lease operating expenses |
$ |
1.78 |
$ |
1.52 |
$ |
0.26 |
17.1% | |||
Gathering and transportation costs and production taxes |
0.25 |
0.31 |
(0.06) |
-19.4% | ||||||
Depreciation, depletion, amortization and accretion |
1.88 |
1.75 |
0.13 |
7.4% | ||||||
General and administrative expenses |
0.69 |
0.65 |
0.04 |
6.2% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||
Condensed Operating Data | ||||||||||
(Unaudited) | ||||||||||
Twelve Months Ended |
||||||||||
December 31, |
Variance | |||||||||
2017 |
2016 |
Variance |
Percentage(2) | |||||||
Net sales volumes: |
||||||||||
Oil (MBbls) |
7,064 |
7,201 |
(137) |
-1.9% | ||||||
NGL (MBbls) |
1,382 |
1,542 |
(160) |
-10.4% | ||||||
Oil and NGLs (MBbls) |
8,446 |
8,743 |
(297) |
-3.4% | ||||||
Natural gas (MMcf) |
36,754 |
39,731 |
(2,977) |
-7.5% | ||||||
Total oil and natural gas (MBoe) (1) |
14,571 |
15,365 |
(794) |
-5.2% | ||||||
Total oil and natural gas (MMcfe) (1) |
87,428 |
92,188 |
(4,760) |
-5.2% | ||||||
Average daily equivalent sales (Boe/d) |
39.9 |
42.0 |
(2.1) |
-4.9% | ||||||
Average daily equivalent sales (MMcfe/d) |
239.5 |
251.9 |
(12.4) |
-4.9% | ||||||
Average realized sales prices: |
||||||||||
Oil ($/Bbl) |
$ |
48.13 |
$ |
37.35 |
$ |
10.78 |
28.9% | |||
NGLs ($/Bbl) |
23.35 |
17.14 |
6.21 |
36.2% | ||||||
Oil and NGLs ($/Bbl) |
44.08 |
33.79 |
10.29 |
30.5% | ||||||
Natural gas ($/Mcf) |
2.96 |
2.53 |
0.43 |
17.0% | ||||||
Barrel of oil equivalent ($/Boe) |
33.02 |
25.76 |
7.26 |
28.2% | ||||||
Natural gas equivalent ($/Mcfe) |
5.50 |
4.29 |
1.21 |
28.2% | ||||||
Average per Boe ($/Boe): |
||||||||||
Lease operating expenses |
$ |
9.86 |
$ |
9.92 |
$ |
(0.06) |
-0.6% | |||
Gathering and transportation costs and production taxes |
1.52 |
1.62 |
(0.10) |
-6.2% | ||||||
Depreciation, depletion, amortization and accretion |
10.68 |
13.77 |
(3.09) |
-22.4% | ||||||
General and administrative expenses |
4.10 |
3.89 |
0.21 |
5.4% | ||||||
Average per Mcfe ($/Mcfe): |
||||||||||
Lease operating expenses |
$ |
1.64 |
$ |
1.65 |
$ |
(0.01) |
-0.6% | |||
Gathering and transportation costs and production taxes |
0.25 |
0.27 |
(0.02) |
-7.4% | ||||||
Depreciation, depletion, amortization and accretion |
1.78 |
2.30 |
(0.52) |
-22.6% | ||||||
General and administrative expenses |
0.68 |
0.65 |
0.03 |
4.6% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||
Condensed Consolidated Balance Sheets | |||||
(Unaudited) | |||||
December 31, |
December 31, | ||||
2017 |
2016 | ||||
(In thousands, except | |||||
share data) | |||||
Assets |
|||||
Current assets: |
|||||
Cash and cash equivalents |
$ |
99,058 |
$ |
70,236 | |
Receivables: |
|||||
Oil and natural gas sales |
45,443 |
43,073 | |||
Joint interest |
19,754 |
21,885 | |||
Insurance reimbursement |
- |
30,100 | |||
Income taxes |
13,006 |
11,943 | |||
Total receivables |
78,203 |
107,001 | |||
Prepaid expenses and other assets |
13,419 |
14,504 | |||
Total current assets |
190,680 |
191,741 | |||
Property and equipment |
8,123,875 |
7,953,402 | |||
Less accumulated depreciation, depletion and amortization |
7,544,859 |
7,406,349 | |||
Net property and equipment |
579,016 |
547,053 | |||
Restricted deposits for asset retirement obligations |
25,394 |
27,371 | |||
Income tax receivables |
52,097 |
52,097 | |||
Escrow deposit - Apache lawsuit |
49,500 |
- | |||
Other assets |
10,893 |
11,464 | |||
Total assets |
$ |
907,580 |
$ |
829,726 | |
Liabilities and Shareholders' Deficit |
|||||
Current liabilities: |
|||||
Accounts payable |
$ |
83,665 |
$ |
81,039 | |
Undistributed oil and natural gas proceeds |
20,129 |
26,254 | |||
Asset retirement obligations |
23,613 |
78,264 | |||
Long-term debt |
22,925 |
8,272 | |||
Accrued liabilities |
17,930 |
9,200 | |||
Total current liabilities |
168,262 |
203,029 | |||
Long-term debt: |
|||||
Principal |
889,790 |
873,733 | |||
Carrying value adjustments |
79,337 |
138,722 | |||
Long-term debt, less current portion - carrying value |
969,127 |
1,012,455 | |||
Asset retirement obligations, less current portion |
276,833 |
256,174 | |||
Apache lawsuit liability |
49,500 |
- | |||
Other liabilities |
17,366 |
17,105 | |||
Commitments and contingencies |
- |
- | |||
Shareholders' deficit: |
|||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 141,960,462 issued and 139,091,289 outstanding at December 31, 2017; 140,543,545 issued and 137,674,372 outstanding at December 31, 2016 |
1 |
1 | |||
Additional paid-in capital |
545,820 |
539,973 | |||
Retained earnings (deficit) |
(1,095,162) |
(1,174,844) | |||
Treasury stock, at cost |
(24,167) |
(24,167) | |||
Total shareholders' deficit |
(573,508) |
(659,037) | |||
Total liabilities and shareholders' deficit |
$ |
907,580 |
$ |
829,726 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||
Condensed Consolidated Statements of Cash Flows | |||||
(Unaudited) | |||||
Twelve Months Ended | |||||
December 31, | |||||
2017 |
2016 | ||||
(In thousands) | |||||
Operating activities: |
|||||
Net Income (loss) |
$ |
79,682 |
$ |
(249,020) | |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
|||||
Depreciation, depletion, amortization and accretion |
155,682 |
211,609 | |||
Ceiling test write-down of oil and natural gas properties |
- |
279,063 | |||
Gain on exchange of debt |
(7,811) |
(123,923) | |||
Debt issuance costs write-down/amortization of debt items |
1,715 |
2,548 | |||
Share-based compensation |
7,191 |
11,013 | |||
Derivative (gain) loss |
(4,199) |
2,926 | |||
Cash receipts on derivative settlements, net |
4,199 |
4,746 | |||
Deferred income taxes |
217 |
28,392 | |||
Changes in operating assets and liabilities: |
|||||
Oil and natural gas receivables |
(2,371) |
(7,005) | |||
Joint interest receivables |
2,131 |
12 | |||
Insurance reimbursements |
31,740 |
- | |||
Income taxes |
(1,063) |
(64,274) | |||
Prepaid expenses and other assets |
3,238 |
(14,946) | |||
Escrow deposit - Apache lawsuit |
(49,500) |
- | |||
Asset retirement obligation settlements |
(72,409) |
(72,320) | |||
Accounts payable, accrued liabilities and other |
10,966 |
5,359 | |||
Net cash provided by operating activities |
159,408 |
14,180 | |||
Investing activities: |
|||||
Investment in oil and natural gas properties and equipment |
(130,048) |
(48,606) | |||
Changes in operating assets and liabilities associated with investing activities |
23,874 |
(35,194) | |||
Proceeds from sales of assets |
- |
1,500 | |||
Purchases of furniture, fixtures and other |
(933) |
(96) | |||
Net cash used in investing activities |
(107,107) |
(82,396) | |||
Financing activities: |
|||||
Borrowings of long-term debt - revolving bank credit facility |
- |
340,000 | |||
Repayments of long-term debt - revolving bank credit facility |
- |
(340,000) | |||
Issuance of 1.5 Lien Term Loan |
- |
75,000 | |||
Payment of interest on 1.5 Lien Term Loan |
(8,227) |
(2,570) | |||
Payment of interest on 2nd Lien PIK Toggle Notes |
(7,335) |
- | |||
Payment of interest on 3rd Lien PIK Toggle Notes |
(6,201) |
- | |||
Debt exchange/issuance costs |
(421) |
(18,464) | |||
Other |
(1,295) |
(928) | |||
Net cash provided by (used in) financing activities |
(23,479) |
53,038 | |||
Increase (decrease) in cash and cash equivalents |
28,822 |
(15,178) | |||
Cash and cash equivalents, beginning of period |
70,236 |
85,414 | |||
Cash and cash equivalents, end of period |
$ |
99,058 |
$ |
70,236 |
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 (Loss) to Net Income (Loss) Excluding Special Items
"Net Income (Loss) Excluding Special Items" does not include the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, write-down of debt issue costs, ceiling test write-down of oil and natural gas properties, gain on exchange of debt, Apache lawsuit, East Cameron 321 settlement, civil penalties, certain cost recovery from insurance settlement, and associated income tax adjustments. 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, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
(In thousands, except per share amounts) | |||||||||||
(Unaudited) | |||||||||||
Net income (loss) |
$ |
23,365 |
$ |
16,483 |
$ |
79,682 |
$ |
(249,020) | |||
Unrealized commodity derivative loss |
841 |
65 |
- |
7,672 | |||||||
Default in payment by joint interest partners |
28 |
1,622 |
888 |
3,615 | |||||||
Write-down debt issue costs |
- |
- |
- |
1,368 | |||||||
Ceiling test write-down of oil and natural gas properties |
- |
- |
- |
279,063 | |||||||
Gain on exchange of debt |
- |
37 |
(7,811) |
(123,923) | |||||||
Apache lawsuit |
- |
- |
6,285 |
- | |||||||
EC 321 settlement |
- |
- |
(1,109) |
- | |||||||
Civil Penalties |
- |
- |
1,820 |
- | |||||||
Certain cost recovery from insurance settlement |
- |
(11,028) |
- |
(11,028) | |||||||
Income tax adjustment for the items above |
(59) |
540 |
(14) |
(23,202) | |||||||
Net income (loss) excluding special items |
$ |
24,175 |
$ |
7,719 |
$ |
79,741 |
$ |
(115,455) | |||
Basic and diluted income (loss) per common share, excluding special items |
$ |
0.17 |
$ |
0.06 |
$ |
0.56 |
$ |
(1.21) |
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Reconciliation of Net Income (Loss) to Adjusted EBITDA
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, gain on exchange of debt, Apache lawsuit, East Cameron 321 settlement, civil penalties, and write-down of debt issue costs. 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 (loss), 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 (loss) to EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Three Months Ended |
Twelve Months Ended | ||||||||||
December 31, |
December 31, | ||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||
(In thousands) | |||||||||||
(Unaudited) | |||||||||||
Net income (loss) |
$ |
23,365 |
$ |
16,483 |
$ |
79,682 |
$ |
(249,020) | |||
Income tax expense (benefit) |
(1,490) |
1,017 |
(12,569) |
(43,376) | |||||||
Net interest expense |
11,290 |
11,508 |
45,521 |
92,109 | |||||||
Depreciation, depletion, amortization and accretion |
38,839 |
38,883 |
155,682 |
211,609 | |||||||
Ceiling test write-down of oil and natural gas properties |
- |
- |
- |
279,063 | |||||||
EBITDA |
72,004 |
67,891 |
268,316 |
290,385 | |||||||
Adjustments: |
|||||||||||
Unrealized commodity derivative (gain) loss |
841 |
65 |
- |
7,672 | |||||||
Default in payment by joint interest partners |
28 |
1,622 |
888 |
3,615 | |||||||
Gain on exchange of debt |
- |
37 |
(7,811) |
(123,923) | |||||||
Apache lawsuit |
- |
- |
6,285 |
- | |||||||
EC 321 settlement |
- |
- |
(1,109) |
- | |||||||
Civil Penalties |
- |
- |
1,820 |
- | |||||||
Write-down debt issue costs |
- |
- |
- |
1,368 | |||||||
Adjusted EBITDA |
$ |
72,873 |
$ |
69,615 |
$ |
268,389 |
$ |
179,117 | |||
Adjusted EBITDA Margin |
56% |
60% |
55% |
45% |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-fourth-quarter-2017-operational-and-financial-results-year-end-2017-proved-reserves-2018-guidance-and-2018-capital-plan-300606273.html
SOURCE W&T Offshore, Inc.
HOUSTON, Feb. 23, 2018 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its fourth quarter 2017 financial and operational results after the market closes on Wednesday, February 28, 2018. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Thursday, March 1 at 10:00 a.m. Eastern Time (9:00 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through March 8, 2018 by dialing 1-201-612-7415 and using the passcode 13676094. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
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 approximately 50 producing fields in federal and state waters and has under lease approximately 710,000 gross acres, including approximately 460,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Investor Relations |
SVP & CFO | |
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-fourth-quarter-2017-financial-and-operational-results-release-and-conference-call-schedule-300603385.html
SOURCE W&T Offshore, Inc.
HOUSTON, Dec. 21, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today provides an update on its Gulf of Mexico shelf operations at Ship Shoal 300, Main Pass 286 and South Timbalier 224, and updates production guidance.
The Company's recently drilled Ship Shoal 300 B-5 ST exploratory well was successful and achieved first production in mid-November. The well logged 173 feet of hydrocarbon pay in multiple stacked oil sands in a previously undrilled fault block, successfully extending the aerial limits of the field. The well was completed as a dual-zone completion and achieved a peak initial production rate of approximately 1,100 barrels of oil equivalent ("Boe") per day (95% oil) from the initial two completion intervals and is set up and equipped for additional future behind-pipe recompletions in these newly penetrated multiple stacked oil sands.
The SS 300 B-5 ST well has outperformed the Company's pre-drill expectations on rate, reserves and value. In addition, the new higher rate from the B-5 well is projected to extend field life several years more than previously estimated, adding significant reserves and value to the overall Ship Shoal 299 field (which includes the SS 300 block). W&T holds a 79% working interest in and is the operator of this Gulf of Mexico shelf well.
The Main Pass 286 #1 exploratory well has reached total depth of 14,562 feet and has logged 112 feet of oil pay. The well is currently being temporarily abandoned in preparation for completion and tie back. The well is in an open water location and will be produced to W&T's Main Pass 283 facility. We expect first production within the next 12 to 15 months. W&T holds a 100% working interest in and is the operator of this Gulf of Mexico shelf well.
The South Timbalier 224 #1 exploratory well recently reached target depth of 10,900 feet and has been deemed non-commercial. W&T holds a 39% working interest in and is the operator of this Gulf of Mexico shelf well. This is the Company's only dry hole in the last several years.
The Company is also currently drilling the Ship Shoal 349 (Mahogany) A-17 well and a rig is being mobilized to our Viosca Knoll 823 (Virgo) platform in approximately 1,100 feet water depth to begin a three well drilling campaign in this deepwater program.
During a semi-annual redetermination, the Company's borrowing base of its revolving bank credit facility has been reaffirmed at $150 million. Currently, the credit facility is essentially undrawn with $149.7 million of availability.
Tracy Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "Our Ship Shoal 299 field is another great example of how integrated technical teams applying the appropriate technology can add materially to shareholder value. Our Ship Shoal 299 field has long been a key producer for us, producing more than 35 million barrels of oil equivalent since first coming on line in 1991. Along with the Main Pass 286 prospect, our teams are still finding untapped resources and adding material value through our advanced technology. Our drilling program continues to make key discoveries and extend the success which landed us twice on the Top 12 Recent Gulf of Mexico Discoveries as reported by E&P Magazine.
"We recently reached total depth at our Main Pass 286 well and have encountered a very nice oil bearing column. This oil discovery is the first new wildcat success by the industry in the Main Pass Protraction Area in over a decade. This is a prospect that was generated in house based on a reprocessed 3D seismic survey. The well will be tied back to W&T's Main Pass 283 facility resulting in improved economics. This is another successful shelf discovery this year following on the heels of our SS 300 B-5 ST well and the various successful wells at Mahogany."
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 approximately 50 producing fields in federal and state waters and has under lease approximately 710,000 gross acres, including approximately 460,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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, 2016 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Investor Relations |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-provides-operations-update-300574221.html
SOURCE W&T Offshore, Inc.
HOUSTON, Dec. 6, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that the Company will be participating in the Capital One Securities 12th Annual Energy Conference to be held in New Orleans on December 4-6, 2017.
Tracy Krohn, W&T Offshore's Chairman and CEO, is scheduled to make a presentation on Wednesday, December 6 at 2:30 p.m. Central Time. The presentation will provide an update on the Company's operations and will be broadcast over the Internet. The webcast link to the audio presentation and accompanying slides can be accessed live and for replay by visiting the investor relations section of the Company's website at www.wtoffshore.com.
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 approximately 50 producing fields in federal and state waters and has under lease approximately 710,000 gross acres, including approximately 460,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Investor Relations |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-to-present-at-the-capital-one-securities-12th-annual-energy-conference-300567454.html
SOURCE W&T Offshore, Inc.
HOUSTON, Nov. 1, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its third quarter 2017 operational and financial results. Some of the key items for the quarter and subsequent period include:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "We continue to have great success with the drill bit and are still at a 100% success rate in 2017, which is identical to the last few years at 100%. Through the end of October 2017 we have drilled four successful wells this year and expect more to come. We are in the process of completing the Ship Shoal 300 B-5 ST well, a field extension well in our highly successful SS300 field, which encountered 172 feet of net stacked pay. This Gulf of Mexico shelf well was drilled from our SS 300 B platform and is expected to be on line as soon as we demobilize the rig. We are very encouraged by the success of this well which has exceeded our pre-drill expectations and is adding reserves and value in the field.
"We are currently drilling the A-17 well at Ship Shoal 349 "Mahogany" which is planned to test and extend the western limits of the field. The Mahogany field continues to perform exceptionally well and offers substantial upside potential. As we experienced with the prolific P-sand in the field, the total recoverable reserves resulting from the T-sand have continued to increase since our initial booking. Strong production from the reservoir along with positive drilling results is proving up larger amounts of oil in place. Assuming success, the A-17 well will be on line late in the fourth quarter of 2017. Once we have drilled and completed the A-17 well we will begin drilling the A-5 ST.
"We also have a number of high-quality low-risk exploration opportunities underway or planned for the near-future that offer substantial potential for solid reserve and production additions. We have commenced drilling an exploratory well at South Timbalier 224 and an exploratory well at Main Pass 286. Both wells are in open water locations on the shelf. Assuming success, the South Timbalier well could be online in late 2018 and the Main Pass 286 well in early 2019. Field extension wells are planned at our Ewing Banks 910 field and at Viosca Knoll 823 ("Virgo") towards the end of this year, and that will carry over into what should be a very active 2018," concluded Mr. Krohn.
Production, Revenues and Price: Total production was 3.4 million barrels of oil equivalent ("MMBoe") in the third quarter of 2017, down from 3.8 MMBoe in the third quarter of 2016.
The Mahogany, Ewing Bank 910, and Virgo fields delivered the largest production increases for the third quarter of 2017 compared to the third quarter of 2016 because of our successful work programs. Production for the third quarter of 2017 was negatively impacted by well maintenance, weather, pipeline outages, and platform maintenance that collectively resulted in deferred production of almost 4,900 Boe per day.
Revenues for the third quarter of 2017 increased 3% to $110.3 million compared to $107.4 million in the third quarter of 2016. The increase in revenues was due to a 16% increase in our realized commodity price, offset by a 12% decline in production volumes. We sold 36,459 Boe per day at an average realized sales price of $32.43 per Boe compared to 41,508 Boe per day sold at an average realized sales price of $27.97 per Boe in the third quarter of 2016. In the second quarter of 2017, we sold 43,084 Boe per day at an average realized sales price of $31.10 per Boe.
Lease Operating Expenses: Lease operating expense ("LOE"), which includes base lease operating expenses, insurance premiums, workovers and facilities maintenance, decreased $2.4 million to $35.1 million in the third quarter of 2017 compared to the third quarter of 2016. On a component basis, base lease operating expenses decreased $4.0 million and workover expenses decreased $1.2 million, partially offset by increased facilities maintenance expense of $2.2 million and increased insurance premiums of $0.6 million. Base lease operating expenses decreased primarily due to continued cost reduction efforts by the Company, cost reductions at non-operated properties and lower processing costs at one of our fields. The decrease in workover expenses was primarily due to reclassifying such costs to a capital project as the result of a workover turning into a sidetrack well. The facility maintenance expense increase is primarily due to engine and compressor overhauls and maintenance at several platforms.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for asset retirement obligations ("ARO"), decreased to $10.88 per Boe for the third quarter of 2017 from $13.49 per Boe for the third quarter of 2016. On a nominal basis, DD&A decreased $15.0 million to $36.5 million for the third quarter of 2017 from $51.5 million for the third quarter of 2016 primarily due to a decrease in the DD&A rate per Boe. DD&A decreased primarily due to the ceiling test write-downs recorded during 2016 and lower capital expenditures in relation to DD&A expense during 2016, both of which lowers the full-cost pool subject to DD&A.
General and Administrative Expenses ("G&A"): G&A increased to $15.6 million for the third quarter of 2017 compared to $12.7 million in the third quarter of 2016. Increases in incentive compensation in 2017 and the expense impact of reinstating the Company's match of employee's 401(K) contributions were partially offset by reductions in salaries and share-based compensation. In the third quarter of 2016, no accruals were made for the short-term incentive program and transaction costs related to the Exchange Transaction previously recorded as G&A expenses were reclassified to Gain on Exchange of Debt, which is a transaction completed in September 2016.
Derivative (gain) loss: The third quarter of 2017 reflects a $2.9 million derivative loss associated with our crude oil and natural gas derivative contracts, which includes settled contracts and open contracts recorded at fair value as of September 30, 2017. We entered into derivative contracts for crude oil and natural gas during the first quarter of 2017, relating to a portion of our 2017 estimated production. The third quarter of 2016 reflects a $0.4 million derivative loss for our crude oil and natural gas derivative contracts.
Interest expense: Interest expense, net of amounts capitalized, was $11.6 million in the third quarter of 2017, decreasing 51% from the $23.6 million for the third quarter of 2016. The decrease was primarily attributable to the Exchange Transaction that was completed on September 7, 2016. In addition, interest expense was lower as we had no borrowings on the revolving bank credit facility during the third quarter of 2017 compared to borrowings averaging over $100 million during the third quarter of 2016.
Income Tax: Our income tax expense in the third quarter of 2017 was $5.5 million on pre-tax income of $4.2 million. Under generally accepted accounting principles we are required to use the effective tax rate method in computing income tax expense or benefit for interim periods. Somewhat improving commodity prices and a relatively lower forecasted spend for plug and abandonment work in 2017 revised our forecast which required us to reduce the amount of benefits previously recorded in the first half of 2017 under the effective tax rate method. Based on current information, we expect our full year tax benefit to be around $14 million. In the third quarter of 2016 we recorded a tax benefit of $3.8 million. Our annualized effective tax rate for the third quarter of 2017 and 2016 is not meaningful. The income tax benefit for both periods relates to NOL carryback claims made pursuant to IRC Section 172(f) (related to rules for "specified liability losses"), which permit certain platform dismantlement, well abandonment and site clearance costs to be carried back 10 years. For both periods, adjustments in the valuation allowance offset changes in net deferred tax assets.
As of September 30, 2017, the balance sheet reflects current income tax receivables of $11.6 million and non-current income tax receivables of $52.1 million. The current income tax receivables as of September 30, 2017 relates to our estimated NOL carryback claim for 2017 associated with our plug and abandonment spending in 2017. The non-current income tax receivables relates to our NOL claims for the years 2012, 2013 and 2014 that were carried back to prior years and to an estimated NOL claim for 2017 that is expected to be filed subsequent to December 31, 2017. These carryback claims are made pursuant to IRC Section 172(f) described above.
Net Income (Loss) & Earnings Per Share: For the third quarter of 2017, excluding special items, our adjusted net income was $6.0 million and our earnings per share were $0.04 per share. We reported pre-tax income of $4.2 million, federal income tax expense of $5.5 million and a net loss of $1.3 million or $0.01 per common share. This compares to a third quarter 2016 reported net income of $45.9 million, or $0.48 per common share. Excluding special items (including a non-cash ceiling test write-down of oil and natural gas properties, a gain on exchange of debt, other minor non-operating costs, and an unrealized commodity derivative loss, all net of applicable federal income tax) the adjusted net loss was $22.6 million and adjusted loss per share was $0.24 per share for the third quarter of 2016. (See the "Reconciliation of Net Income (Loss) to Net Income (Loss) 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 in the first nine months of 2017 was $130.3 million compared to net cash used by operating activities of $9.2 million for the same period in 2016, an improvement of $139.5 million between periods. Cash flows from operating activities were $171.9 million in the first nine months of 2017, (before changes in working capital, insurance reimbursements, escrow deposits and ARO settlements), compared to $42.8 million over the same period in 2016. The increase in cash flows was primarily due to higher realized prices for all our commodities - oil, NGLs and natural gas, lower operating costs and lower interest payments.
Our combined average realized sales price per Boe increased 32% in the first nine months of 2017, which caused total revenues to increase $82.6 million (partially offset by total decreases of 4% in production volumes which included extraordinary downtime due to storms, pipeline repairs and platform maintenance). Lease operating expenses decreased $11.8 million, and interest expense, net of amounts capitalized decreased $46.5 million. Other items affecting operating cash flows for the nine months were ARO settlements of $56.2 million (essentially the same as in the prior-year) and the escrow payment related to the Apache lawsuit of $49.5 million, partially offset by insurance reimbursements of $31.7 million and changes in receivables, accounts payable and accrued liabilities of $30.2 million.
Adjusted EBITDA for the third quarter of 2017 was $57.2 million, up $4.7 million compared to the third quarter of 2016. Our Adjusted EBITDA margin was 52% in the third quarter of 2017, compared to 49% in the third quarter of 2016. Adjusted EBITDA for the first nine months of 2017 was $195.5 million, up $85.7 million over the same period in 2016. Our Adjusted EBITDA margin was 55% for the first nine months of 2017, up from 39% in the first nine months of 2016.
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 September 30, 2017, our total liquidity was $255.9 million, consisting of an unrestricted cash balance of $106.2 million and $149.7 million of availability under our $150 million revolving bank credit facility.
Capital Expenditures: Our capital expenditures for oil and gas properties on an accrual basis for the first nine months of 2017 were $79.1 million compared to $24.1 million for the same period in 2016 ($73.4 million in the 2017 period on a cash basis compared to $61.5 million for the 2016 period). In the first nine months of 2017 over half of our capital expenditures were dedicated to the four wells at our Mahogany field while the remainder was dedicated to a new drill well at Ship Shoal 300, recompletions at Main Pass 69 and High Island 22 and a number of other fields. The remainder of the expenditures was associated with development activities and seismic.
For 2017, our capital budget remains at $125.0 million. Our plug and abandonment activities for 2017 are currently estimated at approximately $70.0 million. Capital expenditures and abandonment activities are expected to be funded with cash on hand and cash flow from operating activities.
OPERATIONS UPDATE
We currently have three rigs operating in the Gulf of Mexico.
Ship Shoal 349 "Mahogany" (100% WI, operated, shelf): We are drilling the A-17 well, which will test and extend the western limits of the field and the large T-sand reservoir. Following the A-17 well, we plan to drill the A-5 ST well targeting the 'Q' and 'P' sands that were logged and evaluated in the A-18 well drilled earlier this year. Workover and recompletion opportunities also exist at Mahogany and will be done as time and operating conditions permit. Mahogany production has averaged over 7,700 Boe per day net to our interest in 2017.
Ship Shoal 300 B-5 ST (79% WI, operated, shelf): Completion operations are currently underway at our SS 300 B-5 ST well, which reached total depth of 5,772 feet on September 26, 2017. This exploration well should be on line in the fourth quarter of 2017 and is being completed as a dual producer. This is an extension well in the highly successful SS300 field. The well was drilled from our SS 300 B platform and encountered 172 feet of net stacked pay.
South Timbalier 224 (39% WI, operated, shelf): In mid-October 2017, we mobilized a rig on location to begin drilling an exploration well at ST 224 in approximately 170 feet of water. Seismic indicates a large amplitude supported prospect located in a working analog producing field trend. Although the well is in an open water location, it is located near existing infrastructure and if successful could be hooked up to any number of relatively nearby platforms and placed on production in late 2018.
Viosca Knoll 823 "Virgo" (80% WI, operated, deepwater): The A-10 ST well is expected to be the first well in a multi-well drilling program at our Virgo field and drilled off of the Virgo platform. If successful this well could be online in the first quarter of 2018. Two additional wells, the A-12 and the A-2ST wells, are also expected to be drilled following completion operations of the A-10 ST. Assuming success, these wells can be brought on line relatively quickly.
Ewing Bank 910 (36% - 50% WI, operated, deepwater): Two wells are planned in our Ewing Bank 910 field, which are the South Timbalier 311 A-2 and A-3 wells. We anticipate beginning rig mobilization in the fourth quarter of 2017 with a likely spud in the middle of the first quarter of 2018. We view both of these wells to be low-risk exploration opportunities with multiple stacked pay sands. If successful, these wells can be brought on line quickly via existing infrastructure and pipelines.
Main Pass 286 (100% WI, operated, shelf): This is an exploratory well that is currently being drilled in an open water location in 300 feet of water that is near existing infrastructure owned by W&T. The target is a strong amplitude variation with offset (AVO) supported Middle Miocene oil prospect in the Cris I sand at a target depth of 14,100'.
Well Recompletions and Workovers: The Main Pass 69 E-1 recompletion was finished and put on line recently. We have another six recompletions of various wells to do for the remainder of this year. So far this year, we have performed eleven recompletions that added approximately 2,400 Boe per day of production and ten workovers that have added approximately 5,400 Boe per day of production.
Fourth Quarter and Full Year 2017 Outlook:
Our guidance for the fourth quarter and full year 2017 in the table below represents the Company's best estimate of the range of likely future results. Fourth quarter guidance reflects approximately 174,000 Boe or over five days of production deferrals related to downtime associated with Hurricane Nate in October 2017. Guidance could be affected by the factors described below in "Forward-Looking Statements."
Fourth Quarter |
Prior Full Year |
Revised Full Year | |||
Production |
2017 |
2017 |
2017 | ||
Oil and NGL's (MMBbls) |
2.0 - 2.2 |
8.4 - 9.3 |
8.3 - 8.8 | ||
Natural Gas (Bcf) |
8.8 - 9.7 |
36.1 - 40.0 |
36.1 - 38.3 | ||
Total (Bcfe) |
20.7 - 22.8 |
86.9 - 96.0 |
85.8 - 91.1 | ||
Total (MMBoe) |
3.4 - 3.8 |
14.5 - 16.0 |
14.3 - 15.2 | ||
Operating Expenses |
Fourth Quarter |
Prior Full Year |
Revised Full Year | ||
($ in millions) |
2017 |
2017 |
2017 | ||
Lease operating expenses |
$37 - $41 |
$149 - $165 |
$139 - $153 | ||
Gathering, transportation & |
|||||
production taxes |
$6 - $7 |
$25 - $28 |
$22 - $25 | ||
General and administrative |
$14 - $16 |
$56 - $62 |
$58 - $62 | ||
Income tax rate benefit |
32% |
26% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, November 2, 2017, 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. An updated investor presentation can be accessed from the Company's website. A replay of the conference call will be available after the call until November 9, 2017, and may be accessed by calling 201-612-7415 and using the passcode 13672623#.
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 approximately 50 producing fields in federal and state waters and has under lease approximately 710,000 gross acres, including approximately 460,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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, 2016 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 | ||||||||||||||
Condensed Consolidated Statements of Income (Loss) | ||||||||||||||
(Unaudited) | ||||||||||||||
Three Months Ended |
Nine Months Ended | |||||||||||||
September 30, |
September 30, | |||||||||||||
2017 |
2016 |
2017 |
2016 | |||||||||||
(In thousands, except per share data) | ||||||||||||||
Revenues |
$ |
110,281 |
$ |
107,403 |
$ |
357,997 |
$ |
284,773 | ||||||
Operating costs and expenses: |
||||||||||||||
Lease operating expenses |
35,134 |
37,520 |
106,817 |
118,611 | ||||||||||
Gathering, transportation costs and production taxes |
4,448 |
5,643 |
16,939 |
18,029 | ||||||||||
Depreciation, depletion, amortization and accretion |
36,489 |
51,500 |
116,843 |
172,726 | ||||||||||
Ceiling test write-down of oil and natural gas properties |
- |
57,912 |
- |
279,063 | ||||||||||
General and administrative expenses |
15,631 |
12,692 |
45,379 |
45,370 | ||||||||||
Derivative (gain) loss |
2,879 |
412 |
(4,765) |
2,861 | ||||||||||
Total costs and expenses |
94,581 |
165,679 |
281,213 |
636,660 | ||||||||||
Operating income (loss) |
15,700 |
(58,276) |
76,784 |
(351,887) | ||||||||||
Interest expense, net of amounts capitalized |
11,554 |
23,618 |
34,284 |
80,760 | ||||||||||
Gain on exchange of debt |
- |
123,960 |
7,811 |
123,960 | ||||||||||
Other (income) expense, net |
(41) |
(73) |
5,073 |
1,209 | ||||||||||
Income (loss) before income tax expense (benefit) |
4,187 |
42,139 |
45,238 |
(309,896) | ||||||||||
Income tax expense (benefit) |
5,484 |
(3,789) |
(11,079) |
(44,393) | ||||||||||
Net income (loss) |
$ |
(1,297) |
$ |
45,928 |
$ |
56,317 |
$ |
(265,503) | ||||||
Basic and diluted earnings (loss) per common share |
$ |
(0.01) |
$ |
0.48 |
$ |
0.39 |
$ |
(3.25) | ||||||
Weighted average common shares outstanding |
137,575 |
92,243 |
137,547 |
81,748 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Three Months Ended |
||||||||||||
September 30, |
Variance | |||||||||||
2017 |
2016 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
1,700 |
1,791 |
(91) |
-5.1% | ||||||||
NGL (MBbls) |
299 |
372 |
(73) |
-19.6% | ||||||||
Oil and NGLs (MBbls) |
1,999 |
2,163 |
(164) |
-7.6% | ||||||||
Natural gas (MMcf) |
8,130 |
9,935 |
(1,805) |
-18.2% | ||||||||
Total oil and natural gas (MBoe) (1) |
3,354 |
3,819 |
(465) |
-12.2% | ||||||||
Total oil and natural gas (MMcfe) (1) |
20,125 |
22,912 |
(2,787) |
-12.2% | ||||||||
Average daily equivalent sales (Boe/d) |
36.4 |
41.5 |
(5.1) |
-12.2% | ||||||||
Average daily equivalent sales (MMcfe/d) |
218.8 |
249.0 |
(30.3) |
-12.2% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
45.92 |
$ |
39.62 |
$ |
6.30 |
15.9% | |||||
NGLs ($/Bbl) |
22.07 |
18.02 |
4.05 |
22.5% | ||||||||
Oil and NGLs ($/Bbl) |
42.35 |
35.91 |
6.44 |
17.9% | ||||||||
Natural gas ($/Mcf) |
2.97 |
2.93 |
0.04 |
1.4% | ||||||||
Barrel of oil equivalent ($/Boe) |
32.43 |
27.97 |
4.46 |
15.9% | ||||||||
Natural gas equivalent ($/Mcfe) |
5.40 |
4.66 |
0.74 |
15.9% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
10.48 |
$ |
9.82 |
$ |
0.66 |
6.7% | |||||
Gathering and transportation costs and production taxes |
1.33 |
1.48 |
(0.15) |
-10.1% | ||||||||
Depreciation, depletion, amortization and accretion |
10.88 |
13.49 |
(2.61) |
-19.3% | ||||||||
General and administrative expenses |
4.66 |
3.32 |
1.34 |
40.4% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.75 |
$ |
1.64 |
$ |
0.11 |
6.7% | |||||
Gathering and transportation costs and production taxes |
0.22 |
0.25 |
(0.03) |
-12.0% | ||||||||
Depreciation, depletion, amortization and accretion |
1.81 |
2.25 |
(0.44) |
-19.6% | ||||||||
General and administrative expenses |
0.78 |
0.55 |
0.23 |
41.8% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Nine Months Ended |
||||||||||||
September 30, |
Variance | |||||||||||
2017 |
2016 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
5,428 |
5,532 |
(104) |
-1.9% | ||||||||
NGL (MBbls) |
1,024 |
1,180 |
(156) |
-13.2% | ||||||||
Oil and NGLs (MBbls) |
6,451 |
6,712 |
(261) |
-3.9% | ||||||||
Natural gas (MMcf) |
28,005 |
29,696 |
(1,691) |
-5.7% | ||||||||
Total oil and natural gas (MBoe) (1) |
11,119 |
11,661 |
(542) |
-4.6% | ||||||||
Total oil and natural gas (MMcfe) (1) |
66,714 |
69,967 |
(3,253) |
-4.6% | ||||||||
Average daily equivalent sales (Boe/d) |
40.7 |
42.6 |
(1.8) |
-4.3% | ||||||||
Average daily equivalent sales (MMcfe/d) |
244.4 |
255.4 |
(11.0) |
-4.3% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
45.81 |
$ |
35.01 |
$ |
10.80 |
30.8% | |||||
NGLs ($/Bbl) |
21.88 |
15.85 |
6.03 |
38.0% | ||||||||
Oil and NGLs ($/Bbl) |
42.01 |
31.64 |
10.37 |
32.8% | ||||||||
Natural gas ($/Mcf) |
2.97 |
2.33 |
0.64 |
27.5% | ||||||||
Barrel of oil equivalent ($/Boe) |
31.85 |
24.15 |
7.70 |
32.0% | ||||||||
Natural gas equivalent ($/Mcfe) |
5.31 |
4.02 |
1.29 |
32.0% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
9.61 |
$ |
10.17 |
$ |
(0.56) |
-5.5% | |||||
Gathering and transportation costs and production taxes |
1.52 |
1.55 |
(0.03) |
-1.9% | ||||||||
Depreciation, depletion, amortization and accretion |
10.51 |
14.81 |
(4.30) |
-29.0% | ||||||||
General and administrative expenses |
4.08 |
3.89 |
0.19 |
4.9% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.60 |
$ |
1.70 |
$ |
(0.10) |
-5.9% | |||||
Gathering and transportation costs and production taxes |
0.25 |
0.26 |
(0.01) |
-3.8% | ||||||||
Depreciation, depletion, amortization and accretion |
1.75 |
2.47 |
(0.72) |
-29.1% | ||||||||
General and administrative expenses |
0.68 |
0.65 |
0.03 |
4.6% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Balance Sheets | |||||||
(Unaudited) | |||||||
September 30, |
December 31, | ||||||
2017 |
2016 | ||||||
(In thousands, except | |||||||
share data) | |||||||
Assets |
|||||||
Current assets: |
|||||||
Cash and cash equivalents |
$ |
106,164 |
$ |
70,236 | |||
Receivables: |
|||||||
Oil and natural gas sales |
39,165 |
43,073 | |||||
Joint interest |
21,877 |
21,885 | |||||
Insurance reimbursement |
- |
30,100 | |||||
Income taxes |
11,623 |
11,943 | |||||
Total receivables |
72,665 |
107,001 | |||||
Prepaid expenses and other assets |
15,073 |
14,504 | |||||
Total current assets |
193,902 |
191,741 | |||||
Property and equipment |
8,065,626 |
7,953,402 | |||||
Less accumulated depreciation, depletion and amortization |
7,510,372 |
7,406,349 | |||||
Net property and equipment |
555,254 |
547,053 | |||||
Restricted deposits for asset retirement obligations |
25,339 |
27,371 | |||||
Income tax receivables |
52,097 |
52,097 | |||||
Escrow deposit - Apache lawsuit |
49,500 |
- | |||||
Other assets |
11,279 |
11,464 | |||||
Total assets |
$ |
887,371 |
$ |
829,726 | |||
Liabilities and Shareholders' Deficit |
|||||||
Current liabilities: |
|||||||
Accounts payable |
$ |
72,197 |
$ |
81,039 | |||
Undistributed oil and natural gas proceeds |
20,084 |
26,254 | |||||
Asset retirement obligations |
29,456 |
78,264 | |||||
Long-term debt |
11,147 |
8,272 | |||||
Accrued liabilities |
26,550 |
9,200 | |||||
Total current liabilities |
159,434 |
203,029 | |||||
Long-term debt: |
|||||||
Principal |
873,733 |
873,733 | |||||
Carrying value adjustments |
108,884 |
138,722 | |||||
Long-term debt, less current portion - carrying value |
982,617 |
1,012,455 | |||||
Asset retirement obligations, less current portion |
275,560 |
256,174 | |||||
Apache lawsuit liability |
49,500 |
- | |||||
Other liabilities |
17,531 |
17,105 | |||||
Commitments and contingencies |
- |
- | |||||
Shareholders' deficit: |
|||||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 140,690,917 issued and 137,821,744 outstanding at September 30, 2017; 140,543,545 issued and 137,674,372 outstanding at December 31, 2016 |
1 |
1 | |||||
Additional paid-in capital |
545,422 |
539,973 | |||||
Retained earnings (deficit) |
(1,118,527) |
(1,174,844) | |||||
Treasury stock, at cost |
(24,167) |
(24,167) | |||||
Total shareholders' deficit |
(597,271) |
(659,037) | |||||
Total liabilities and shareholders' deficit |
$ |
887,371 |
$ |
829,726 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||
Condensed Consolidated Statements of Cash Flows | ||||||||
(Unaudited) | ||||||||
Nine Months Ended |
||||||||
September 30, |
||||||||
2017 |
2016 |
|||||||
(In thousands) |
||||||||
Operating activities: |
||||||||
Net Income (loss) |
$ |
56,317 |
$ |
(265,503) |
||||
Adjustments to reconcile net loss to net cash provided by (used in) operating activities: |
||||||||
Depreciation, depletion, amortization and accretion |
116,843 |
172,726 |
||||||
Ceiling test write-down of oil and natural gas properties |
- |
279,063 |
||||||
Gain on exchange of debt |
(7,811) |
(123,960) |
||||||
Debt issuance costs write-down/amortization of debt items |
1,271 |
2,135 |
||||||
Share-based compensation |
5,449 |
7,642 |
||||||
Derivative (gain) loss |
(4,765) |
2,861 |
||||||
Cash receipts on derivative settlements |
3,924 |
4,746 |
||||||
Deferred income taxes |
321 |
15,484 |
||||||
Changes in operating assets and liabilities: |
||||||||
Oil and natural gas receivables |
3,906 |
294 |
||||||
Joint interest receivables |
8 |
4,281 |
||||||
Insurance reimbursements |
31,740 |
- |
||||||
Income taxes |
320 |
(52,392) |
||||||
Prepaid expenses and other assets |
2,194 |
(16,128) |
||||||
Escrow deposit - Apache lawsuit |
(49,500) |
- |
||||||
Asset retirement obligation settlements |
(56,226) |
(56,167) |
||||||
Accounts payable, accrued liabilities and other |
26,329 |
15,750 |
||||||
Net cash provided by (used in) operating activities |
130,320 |
(9,168) |
||||||
Investing activities: |
||||||||
Investment in oil and natural gas properties and equipment |
(79,088) |
(24,062) |
||||||
Changes in operating assets and liabilities associated with investing activities |
5,679 |
(37,400) |
||||||
Proceeds from sales of assets |
- |
1,500 |
||||||
Purchases of furniture, fixtures and other |
(905) |
(96) |
||||||
Net cash used in investing activities |
(74,314) |
(60,058) |
||||||
Financing activities: |
||||||||
Borrowings of long-term debt - revolving bank credit facility |
- |
340,000 |
||||||
Repayments of long-term debt - revolving bank credit facility |
- |
(340,000) |
||||||
Issuance of 1.5 Lien Term Loan |
- |
75,000 |
||||||
Payment of interest on 1.5 Lien Term Loan |
(6,170) |
- |
||||||
Payment of interest on 2nd Lien PIK Toggle Notes |
(7,335) |
- |
||||||
Payment of interest on 3rd Lien PIK Toggle Notes |
(6,201) |
- |
||||||
Debt exchange/issuance costs |
(421) |
(17,920) |
||||||
Other |
49 |
83 |
||||||
Net cash provided by (used in) financing activities |
(20,078) |
57,163 |
||||||
Increase (decrease) in cash and cash equivalents |
35,928 |
(12,063) |
||||||
Cash and cash equivalents, beginning of period |
70,236 |
85,414 |
||||||
Cash and cash equivalents, end of period |
$ |
106,164 |
$ |
73,351 |
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 (Loss) to Net Income (Loss) Excluding Special Items
"Net Income (Loss) Excluding Special Items" does not include the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, write-down of debt issue costs, ceiling test write-down of oil and natural gas properties, gain on exchange of debt, Apache lawsuit, East Cameron 321 settlement, civil penalties, and associated income tax adjustments. 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 |
Nine Months Ended | ||||||||||||
September 30, |
September 30, | ||||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||||
(In thousands, except per share amounts) | |||||||||||||
(Unaudited) | |||||||||||||
Net income (loss) |
$ |
(1,297) |
$ |
45,928 |
$ |
56,317 |
$ |
(265,503) | |||||
Unrealized commodity derivative (gain) loss |
4,595 |
412 |
(841) |
7,606 | |||||||||
Default in payment by joint interest partners |
385 |
928 |
860 |
2,331 | |||||||||
Write-down debt issue costs |
- |
- |
- |
1,368 | |||||||||
Ceiling test write-down of oil and natural gas properties |
- |
57,912 |
- |
279,063 | |||||||||
Gain on exchange of debt |
- |
(123,960) |
(7,811) |
(123,960) | |||||||||
Apache lawsuit |
- |
- |
6,285 |
- | |||||||||
EC 321 settlement |
- |
- |
(1,109) |
- | |||||||||
Civil Penalties |
- |
- |
1,820 |
- | |||||||||
Income tax adjustment for the items above |
(1,743) |
(3,789) |
279 |
(23,796) | |||||||||
Income tax adjustment for effective tax rate for the quarter |
4,019 |
- |
- |
- | |||||||||
Net income (loss) excluding special items |
$ |
5,959 |
$ |
(22,569) |
$ |
55,800 |
$ |
(122,891) | |||||
Basic and diluted income (loss) per common share, excluding special items |
$ |
0.04 |
$ |
(0.24) |
$ |
0.39 |
$ |
(1.50) | |||||
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Reconciliation of Net Income (Loss) to Adjusted EBITDA
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, gain on exchange of debt, Apache lawsuit, East Cameron 321 settlement, civil penalties, and write-down of debt issue costs. 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 (loss), 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 (loss) to EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Three Months Ended |
Nine Months Ended | ||||||||||||
September 30, |
September 30, | ||||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||||
(In thousands) | |||||||||||||
(Unaudited) | |||||||||||||
Net income (loss) |
$ |
(1,297) |
$ |
45,928 |
$ |
56,317 |
$ |
(265,503) | |||||
Income tax expense (benefit) |
5,484 |
(3,789) |
(11,079) |
(44,393) | |||||||||
Net interest expense |
11,513 |
23,546 |
34,231 |
80,602 | |||||||||
Depreciation, depletion, amortization and accretion |
36,489 |
51,500 |
116,843 |
172,726 | |||||||||
Ceiling test write-down of oil and natural gas properties |
- |
57,912 |
- |
279,063 | |||||||||
EBITDA |
52,189 |
175,097 |
196,312 |
222,495 | |||||||||
Adjustments: |
|||||||||||||
Unrealized commodity derivative (gain) loss |
4,595 |
412 |
(841) |
7,606 | |||||||||
Default in payment by joint interest partners |
385 |
928 |
860 |
2,331 | |||||||||
Gain on exchange of debt |
- |
(123,960) |
(7,811) |
(123,960) | |||||||||
Apache lawsuit |
- |
- |
6,285 |
- | |||||||||
EC 321 settlement |
- |
- |
(1,109) |
- | |||||||||
Civil Penalties |
- |
- |
1,820 |
- | |||||||||
Write-down debt issue costs |
- |
- |
- |
1,368 | |||||||||
Adjusted EBITDA |
$ |
57,169 |
$ |
52,477 |
$ |
195,516 |
$ |
109,840 | |||||
Adjusted EBITDA Margin |
52% |
49% |
55% |
39% |
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-third-quarter-2017-operational-and-financial-results-300548041.html
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 26, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its third quarter 2017 financial and operational results after the market closes on Wednesday, November 1, 2017. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Thursday, November 2 at 10:00 a.m. Eastern Time (9:00 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through November 9, 2017 by dialing 1-201-612-7415 and using the passcode 13672623. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
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 approximately 50 producing fields in federal and state waters and has under lease approximately 710,000 gross acres, including approximately 460,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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.
CONTACT |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-third-quarter-2017-financial-and-operational-results-release-and-conference-call-schedule-300544466.html
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 2, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that the Company will be participating in the IPAA Oil & Gas Investment Symposia to be held October 3, 2017 in Chicago.
Tracy Krohn, W&T Offshore's Chairman and CEO, is scheduled to make a presentation at 9:20 a.m. Central Time. The presentation will provide an update on the Company's operations and will be broadcast over the Internet. The webcast link to the audio presentation and accompanying slides can be accessed live and for replay by visiting the investor relations section of the Company's website at www.wtoffshore.com.
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 approximately 50 producing fields in federal and state waters and has under lease approximately 730,000 gross acres, including approximately 480,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-to-present-at-the-ipaa-oil--gas-investment-symposia-in-chicago-300529116.html
SOURCE W&T Offshore, Inc.
HOUSTON, Sept. 6, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today announced that W&T experienced relatively minor impacts from Hurricane Harvey in the Gulf of Mexico. In total, the Company's deferred production was approximately 43,000 barrels of oil equivalent and it experienced no material platform damage resulting from the storm. In relative terms, this production deferment is immaterial and represents approximately one day's equivalent production for the Company.
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, commented, "Our operations teams were well prepared for the storm and did a great job avoiding and mitigating issues and re-manning our facilities in a safe and efficient manner. We are pleased to report that we sustained essentially no damage to our offshore assets from the storm and have experienced only a minor amount of deferred production volume."
In preparation for the storm, W&T temporarily shut-in and evacuated a small number of its western Gulf of Mexico (GOM) offshore platforms that were located closer to the Hurricane's projected path. The vast majority of the Company's other offshore production platforms and its offshore drilling operations were all on high alert, but conducted near-normal operations during the storm event and were relatively impact free with minimal downtime. The Company has since re-manned and re-started production from its operated offshore production facilities. One non-operated field located in the western GOM is being prepared for production resumption and is anticipated to come back on line soon. The company experienced no injuries or environmental events and experienced no material platform damage as a result of the storm. The company is currently producing at normal pre-storm production rates.
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 approximately 50 producing fields in federal and state waters and has under lease approximately 730,000 gross acres, including approximately 480,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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, 2016 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-wt-provides-update-on-operations-following-hurricane-harvey-300514160.html
SOURCE W&T Offshore, Inc.
HOUSTON, Sept. 5, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that the Company will be participating in the Barclays CEO Energy-Power Conference to be held September 5-7, 2017 in New York City.
Tracy Krohn, W&T Offshore's Chairman and CEO, is scheduled to make a presentation on Wednesday, September 6, at 12:25 p.m. Eastern Time. The presentation will provide an update on the Company's operations and will be broadcast over the Internet. The webcast link to the audio presentation and accompanying slides can be accessed live and for replay by visiting the investor relations section of the Company's website at www.wtoffshore.com.
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 approximately 50 producing fields in federal and state waters and has under lease approximately 730,000 gross acres, including approximately 480,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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.
Lisa Elliott
Dennard Lascar Associates
lelliott@dennardlascar.com
713-529-6600
Danny Gibbons
SVP & CFO
investorrelations@wtoffshore.com
713-624-7326
View original content:http://www.prnewswire.com/news-releases/wt-offshore-to-present-at-the-barclays-ceo-energy-power-conference-300513633.html
SOURCE W&T Offshore, Inc.
HOUSTON, Sept. 5, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today announced that the Bureau of Ocean Energy Management ("BOEM") has rescinded its four orders issued in 2016 that instructed W&T to provide additional supplemental bonding of $260.8 million. The Company is in compliance with its financial assurance obligations to the BOEM and has no outstanding BOEM orders related to financial assurance obligations.
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "With W&T satisfying the BOEM's demands regarding our sole liability properties, as expected, the BOEM has formally rescinded the orders it issued in 2016 for us to provide additional financial assurance. We are pleased to have this matter resolved and concluded."
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 approximately 50 producing fields in federal and state waters and has under lease approximately 730,000 gross acres, including approximately 480,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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, 2016 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.
Lisa Elliott
Dennard Lascar Associates
lelliott@dennardlascar.com
713-529-6600
Danny Gibbons
SVP & CFO
investorrelations@wtoffshore.com
713-624-7326
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-rescission-of-boem-orders-for-additional-supplemental-bonding-300513632.html
SOURCE W&T Offshore, Inc.
HOUSTON, Aug. 3, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its second quarter 2017 operational and financial results. Some of the key items for the quarter and subsequent period include:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "We are very pleased to be in the final stages of resolving the matter with the BOEM, which has been a significant distraction for W&T and our investors for over a year. We are generating strong cash flow, solid earnings and very attractive EBITDA margins, driven by the performance of our high-quality asset base.
"We have continued to maintain steady production volumes with modest capital outlays as we successfully executed lower-risk, high-return projects in our existing fields. We have also continued to drive down our operating expenses to the lowest levels in many years and generated an EBITDA margin of 59%, which is in-line with the 60-62% EBITDA margins we achieved in 2012-2014 in a much higher commodity price environment. Compared to the first quarter, LOE declined 22% or $8.6 million resulting in higher adjusted EBITDA margins in the second quarter despite the slightly lower commodity prices. While we are hopeful that oil prices will improve from current levels, we have clearly demonstrated that we can be profitable in current market conditions.
"So far in the first half of 2017, our operations have primarily focused on exploiting our Mahogany Field, which continues to perform exceptionally well and offers substantial upside potential. As we have continued drilling, the T-sand reservoir continues to get bigger just like we experienced with the prolific P-sand. In the second half of the year, we will progress our work plan at Mahogany which includes the A-17 well that is also targeting the T-sand, followed by the A-5 ST. Workovers and recompletions will also be performed on wells at Mahogany as time permits. We also have an exploratory well that will spud shortly to drill a low risk undrilled fault block in our SS300 field and exploratory wells planned at Main Pass 286 and South Timbalier 224 both of which are open water locations. New wells are also planned for Ewing Banks 910 field and Viosca Knoll 823 Virgo field towards the end of this year and that will carry over into what should be a busy 2018," concluded Mr. Krohn.
Production, Revenues and Price: Total production was 3.9 million barrels of oil equivalent ("MMBoe") in the second quarter of 2017, up slightly from the second quarter of 2016. Production increases were achieved at various fields including Ship Shoal 349 ("Mahogany"), Garden Banks 302 and Viosca Knoll 783 fields, partially offset by natural production declines from existing wells between the periods. Second quarter 2017 includes revenues of $4.1 million representing royalty relief for oil produced at our Mississippi Canyon 698 ("Big Bend") field in 2016. Oil volumes associated with the royalty relief were 114,867 barrels and are reflected in 2017 production volumes. The Big Bend realized oil price in 2016 was below the average price posted by the government and hence we received royalty relief.
Revenues for the second quarter of 2017 increased 24% to $123.3 million compared to $99.7 million in the second quarter of 2016. The increase in revenues was due to a 23% increase in our realized commodity price. We sold 43,084 Boe per day at an average realized sales price of $31.10 per Boe compared to 42,864 Boe per day sold at an average realized sales price of $25.28 per Boe in the second quarter of 2016. In the first quarter of 2017, we sold 42,712 Boe per day at an average realized sales price of $32.12 per Boe after royalties, transportation and quality bank adjustments.
Lease Operating Expenses: Lease operating expense ("LOE"), which includes base lease operating expenses, insurance premiums, workovers and facilities maintenance, decreased $5.1 million to $31.5 million in the second quarter of 2017 compared to the second quarter of 2016. On a per-Boe basis, LOE decreased to $8.04 per Boe in the second quarter of 2017, a 14.4% reduction compared to $9.39 per Boe in the second quarter of 2016. LOE decreased primarily due to lower costs from service providers along with optimization efforts to reduce our lease operating costs and lower insurance premiums. These reductions were partially offset by higher workover costs of $0.9 million due to an increase in activities.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for asset retirement obligations ("ARO"), decreased to $10.29 per Boe for the second quarter of 2017 from $14.74 per Boe for the second quarter of 2016. On a nominal basis, DD&A decreased $17.1 million to $40.4 million for the second quarter of 2017 from $57.5 million for the second quarter of 2016 primarily due to a decrease in the DD&A rate per Boe, which declined due to prior-period ceiling test write-downs.
General and Administrative Expenses ("G&A"): G&A increased slightly to $16.5 million for the second quarter of 2017 compared to the second quarter of 2016. The increase was primarily due to increases in incentive compensation programs and accrued civil penalties received from BSEE that are being appealed to IBLA, partially offset by lower salary costs, legal expenses, professional fees and surety bond costs.
Derivative (gain) loss: For the second quarter of 2017, there was a $3.7 million derivative gain recorded for both crude oil and natural gas derivative contracts, which includes both open and settled contracts as of June 30, 2017. We entered into derivative contracts for crude oil and natural gas during the first quarter of 2017, relating to a portion of our 2017 estimated production. For the second quarter of 2016, there was a $4.9 million derivative loss recorded for derivative contracts for crude oil and natural gas.
Interest expense: Interest expense, net of amount capitalized, decreased $18.2 million to $11.4 million in the second quarter of 2017, compared to $29.7 million in the second quarter of 2016. The decrease was primarily due to an exchange transaction that was completed on September 7, 2016, when we exchanged $710.2 million of our unsecured senior notes for $301.8 million of new secured notes and 60 million shares of our common stock. Also, there were no borrowings outstanding under our revolving bank credit facility during the second quarter of 2017. Interest paid in cash on the $301.8 million of new secured debt is reported as a reduction of the carrying value of the new secured debt.
Gain on Exchange of Debt: During the second quarter of 2017, an additional net gain of $8.1 million was recognized primarily as a result of paying interest in cash on the Second Lien PIK Toggles Notes and the Third Lien PIK Toggle Notes versus paying the interest through the pay-in-kind ("PIK") option. Under ASC 470-60 accounting guidance that is applicable to us due to our 2016 debt restructuring, the carrying value for the Second and Third Lien PIK Toggle Notes was reduced due to the cash payment. The cash payment has a lower interest rate compared to the PIK option and this also reduces future interest and principal payments. Partially offsetting were additional expenses related to the Exchange Transaction for differences between estimated and actual costs. We anticipate the remaining eligible interest payments will be made in kind versus in cash.
Other (income) expense: For the second quarter of 2017, other (income) expense, net, was $5.2 million consisting primarily of $6.3 million for items related to the Apache litigation matter (described below), partially offset by $1.1 million in loss-of-use reimbursements from a third-party for damages incurred at one of our platforms. In June 2017 we received a final trial court judgment directing us to pay Apache Corp. $43.2 million plus court costs, attorney's fees and pre and post judgment interest of $6.3 million. The judgment stems from a previously disclosed lawsuit that Apache filed in December 2014 regarding a dispute about Apache's use of much more expensive drilling rigs instead of a previously contracted intervention vessel for the plugging and abandonment of three deepwater wells in the Mississippi Canyon area of the Gulf of Mexico. W&T contends that the excess costs of using the drilling rigs were unnecessary and unreasonable but that Apache chose to use the rigs without W&T's consent because they otherwise would have been idle at Apache's expense. W&T believes the use of the rigs was in bad faith, as found by the jury, and that such conduct caused W&T not to comply with the applicable joint operating agreement, particularly since another vessel had been contracted by Apache for the abandonment a year in advance. W&T had previously paid $24.9 million as an undisputed amount for the plug and abandonment work. We intend to appeal the trial court judgment in this lawsuit. In June 2017, in order to stay execution of the judgment, and pending the disposition of post judgment motions, we deposited with the court $49.5 million and have accounted for this as a long-term asset with a corresponding offset recorded as a long-term liability. We have also increased the amount of our asset retirement obligation by an additional $19.9 million (we had previously accrued $23.3 million) and expensed the $6.3 million as indicated above.
Income Tax: Our income tax benefit for the three months ended June 30, 2017 and 2016 was $9.0 million and $35.7 million, respectively. Our annualized effective tax rate for both periods was not meaningful. The income tax benefit for both periods relates to NOL carryback claims made pursuant to IRC Section 172(f) (related to rules for "specified liability losses"), which permit certain platform dismantlement, well abandonment and site clearance costs to be carried back 10 years.
As of June 30, 2017, the balance sheet reflects a current income tax receivable of $12.0 million and non-current income tax receivables of $69.0 million. The current income tax receivable primarily relates to our NOL claim for 2016 carried back to 2006. The non-current income tax receivables relate to our NOL claims that were carried back to earlier years that are expected to be received in 2018. In July 2017, we received income tax refunds of $11.9 million primarily related to our 2016 refund claim.
Net Income (Loss) & Earnings (Loss) Per Share: We reported net income for the second quarter of 2017 of $33.3 million or $0.23 per common share. Excluding special items, our adjusted net income was $31.1 million and our earnings were $0.22 per share. This compares to a second quarter 2016 reported net loss of ($120.9) million, or ($1.58) per common share; excluding special items (including a non-cash ceiling test write-down of oil and natural gas properties) adjusted net loss would have been ($35.8) million, or ($0.47) per share. Compared to the first quarter of 2017, net income, excluding special items, increased $8.3 million or $0.06 per share. (See the "Reconciliation of Net Income (Loss) to Net Income (Loss) 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 in the first six months of 2017 was $65.6 million compared to net cash used by operating activities of $11.3 million for the same period in 2016. Cash flows from operating activities before changes in working capital, insurance reimbursements, escrow deposits and ARO settlements were $112.3 million in the first half of 2017, compared to $6.5 million over the same period in 2016. The increase in cash flows was primarily due to higher realized prices for all our commodities - oil, NGLs and natural gas, lower operating costs and lower interest payments. Our combined average realized sales price per Boe increased 41.8%, which caused total revenues to increase $70.3 million. LOE decreased $9.4 million, G&A decreased $2.9 million and interest expense (the portion of interest that is a part of operating activities and not financing activities) decreased $34.4 million. Other items affecting operating cash flows for the six months ended June 30, 2017 included insurance reimbursements of $30.1 million, changes in receivables, accounts payable and accrued liabilities of $12.3 million, partially offset by ARO expenditures of $36.0 million and a deposit with the court related to the Apache matter of $49.5 million.
Adjusted EBITDA for the second quarter of 2017 was $72.6 million, up $31.8 million over the same period in 2016. Our Adjusted EBITDA margin was 59% in the second quarter of 2017, compared to 41% in the second quarter of 2016 and 52% in the first quarter of 2017. Adjusted EBITDA for the first six months of 2017 was $138.3 million representing an increase of $81.0 million over the first six months of 2016.
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, 2017, our total liquidity was $222.0 million, consisting of an unrestricted cash balance of $72.3 million and $149.7 million of availability under our $150 million revolving bank credit facility. Our total liquidity as of July 26, 2017 was $254.9 million with a cash balance of over $105 million.
Capital Expenditures: Our capital expenditures for oil and gas properties on an accrual basis for the first six months of 2017 were $43.8 million ($44.6 million on a cash basis) compared to $17.7 million ($51.8 million on a cash basis) for the same period in 2016. In the first half of 2017 our capital expenditures were primarily directed at three different wells at Mahogany including the completion operations for the A-18 well, drilling and completion operations of the A-16BP1 and the drilling and completion of the A-8. We also conducted well activity at High Island 22. The remainder of the expenditures was associated with recompletions, development activities and seismic.
For 2017, our capital expenditure budget remains at $125.0 million. Our plug and abandonment activities for 2017 are currently estimated at approximately $82.8 million. Capital expenditures and abandonment activities are expected to be funded with cash on hand and cash flow from operating activities.
BOEM FINANCIAL ASSURANCE
We are in final stages of resolving our current issues with the BOEM that began over a year ago with its demand that W&T provide financial assurances (such as supplemental bonding) totaling $260.8 million.
OPERATIONS UPDATE
We currently have two rigs operating in the Gulf of Mexico, one of which is at Mahogany drilling the A-17 well, and the other is at Ship Shoal 300 rigging up to drill the B-5 well. For the first half of 2017 we have completed three wells all of which are in the Mahogany field.
Ship Shoal 349 "Mahogany" (100% WI, operated, shelf): In mid-April we placed on production the A-16 BP1 well targeting the 'P' Sand. The A-16 well achieved a peak net rate of approximately 1,625 Boe per day and is currently producing almost 1,100 Boe per day and is 83% oil. We then drilled the A-8 well to total depth and completed the well right before the end of the quarter. The well is currently in flow-back and is stabilizing. The rig is now drilling the A-17 well, which should test and extend the western limits of the large T-sand reservoir. Following that well we plan to drill a sidetrack well at the A-5 location targeting the 'Q' and 'P' sands. This well will likely be a 2018 completion. Workover and recomplete opportunities also exist at Mahogany and will be done as time and operating conditions permit. Mahogany production averaged over 8,000 Boe per day in June 2017.
Ship Shoal 300 B-5 (80% WI, operated, shelf): We have mobilized a platform rig to our Ship Shoal 300 field to commence drilling the B-5 well. This well will target multiple stacked pay intervals in an undrilled fault block, which are indicated by strong amplitude features in our new seismic. Assuming the well is successful, we may add a second well to further increase reserves and value. The SS 300 B-5 well is expected to cost approximately $8.4 million to drill and complete and to pay out in less than a year and half.
South Timbalier 224 (39% WI, operated, shelf): This is an exploratory open water location opportunity in 170 feet of water that is near existing infrastructure. Seismic indicates a large, amplitude supported prospect. This well should spud in the fourth quarter of 2017.
Ewing Bank 910 (36% - 50% WI, operated, deepwater): Two wells are planned in our Ewing Bank 910 field, including the South Timbalier 311 A-2 and A-3 sidetrack wells. The first well is expected to spud towards the end of 2017, with the next well to follow shortly thereafter in 2018. We view both of these wells to be low-risk exploration opportunities with multiple stacked pay sands. If successful, these wells can be brought on line quickly via existing infrastructure and pipelines.
Main Pass 286 (100% WI, operated, shelf): This is an exploratory well to be drilled in an open water location in 300 feet of water that is near existing infrastructure owned by W&T. Target is a strong amplitude variation with offset (AVO) supported Middle Miocene oil prospect in the Cris I sand at a target depth of 14,100'. Drilling will likely begin in the fourth quarter of 2017.
Viosca Knoll 823 "Virgo": Two to three wells are planned in our Virgo field later this year and into next year. The first well is the A-10 ST followed by the A-12 and then the A-2 ST. These wells can be drilled from the existing platform and assuming success can be brought on line relatively quickly.
Well Recompletions and Workovers: So far this year, we have completed seven recompletions that added approximately 1,700 Boe per day of production and eight workovers that have added approximately 5,400 Boe per day of production. Cost per flowing Boe for the recompletions was about $9,400 and about $1,050 per Boe for the workovers.
Third Quarter and Full Year 2017 Outlook:
Our guidance for the third quarter and full year 2017 in the table below represents the Company's best estimate of the range of likely future results. Third quarter guidance reflects an estimate of almost 3,000 Boe per day for storm downtime that may or may not occur. To be updated before issuing. Guidance could be affected by the factors described below in "Forward-Looking Statements."
Third Quarter |
Prior Full Year |
Revised Full Year | |||
Production |
2017 |
2017 |
2017 | ||
Oil and NGL's (MMBbls) |
1.9 - 2.2 |
8.7 - 9.7 |
8.4 - 9.3 | ||
Natural Gas (Bcf) |
8.2 - 9.0 |
38.9 - 42.9 |
36.1 - 40.0 | ||
Total (Bcfe) |
19.8 - 21.9 |
91.2 - 100.8 |
86.9 - 96.0 | ||
Total (MMBoe) |
3.3 - 3.7 |
15.2 - 16.8 |
14.5 - 16.0 | ||
Operating Expenses |
Third Quarter |
Prior Full Year |
Revised Full Year | ||
($ in millions) |
2017 |
2017 |
2017 | ||
Lease operating expenses |
$39 - $43 |
$161 - $177 |
$149 - $165 | ||
Gathering, transportation & |
|||||
production taxes |
$6 - $7 |
$26 - $29 |
$25 - $28 | ||
General and administrative |
$14 - $15 |
$58 - $64 |
$56 - $62 | ||
Income tax rate benefit |
46% |
32% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Friday, August 4, 2017, at 10:00 a.m. Eastern 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. An updated investor presentation can be accessed from the Company's website. A replay of the conference call will be available after the call until August 11, 2017, and may be accessed by calling 201-612-7415 and using the passcode 13666117#.
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 approximately 50 producing fields in federal and state waters and has under lease approximately 730,000 gross acres, including approximately 480,000 gross acres on the Gulf of Mexico Shelf and approximately 250,000 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, 2016 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 | |||||||||||||
Condensed Consolidated Statements of Income (Loss) | |||||||||||||
(Unaudited) | |||||||||||||
Three Months Ended |
Six Months Ended | ||||||||||||
June 30, |
June 30, | ||||||||||||
2017 |
2016 |
2017 |
2016 | ||||||||||
(In thousands, except per share data) | |||||||||||||
Revenues |
$ |
123,323 |
$ |
99,655 |
$ |
247,716 |
$ |
177,370 | |||||
Operating costs and expenses: |
|||||||||||||
Lease operating expenses |
31,519 |
36,622 |
71,683 |
81,091 | |||||||||
Gathering, transportation costs and production taxes |
5,767 |
6,768 |
12,491 |
12,386 | |||||||||
Depreciation, depletion, amortization and accretion |
40,364 |
57,493 |
80,354 |
121,226 | |||||||||
Ceiling test write-down of oil and natural gas properties |
- |
104,592 |
- |
221,151 | |||||||||
General and administrative expenses |
16,474 |
16,235 |
29,748 |
32,678 | |||||||||
Derivative (gain) loss |
(3,689) |
4,942 |
(7,644) |
2,449 | |||||||||
Total costs and expenses |
90,435 |
226,652 |
186,632 |
470,981 | |||||||||
Operating income (loss) |
32,888 |
(126,997) |
61,084 |
(293,611) | |||||||||
Interest expense, net of amounts capitalized |
11,436 |
29,671 |
22,730 |
57,142 | |||||||||
Gain on exchange of debt |
8,056 |
- |
7,811 |
- | |||||||||
Other (income) expense, net |
5,168 |
(24) |
5,114 |
1,282 | |||||||||
Income (loss) before income tax benefit |
24,340 |
(156,644) |
41,051 |
(352,035) | |||||||||
Income tax benefit |
(8,975) |
(35,722) |
(16,563) |
(40,604) | |||||||||
Net income (loss) |
$ |
33,315 |
$ |
(120,922) |
$ |
57,614 |
$ |
(311,431) | |||||
Basic and diluted earnings (loss) per common share |
$ |
0.23 |
$ |
(1.58) |
$ |
0.40 |
$ |
(4.07) | |||||
Weighted average common shares outstanding |
137,552 |
76,457 |
137,533 |
76,443 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||||||
Condensed Operating Data | |||||||||||
(Unaudited) | |||||||||||
Three Months Ended |
|||||||||||
June 30, |
Variance | ||||||||||
2017 |
2016 |
Variance |
Percentage(2) | ||||||||
Net sales volumes: |
|||||||||||
Oil (MBbls) |
1,923 |
1,835 |
88 |
4.8% | |||||||
NGL (MBbls) |
351 |
451 |
(100) |
-22.2% | |||||||
Oil and NGLs (MBbls) |
2,272 |
2,286 |
(14) |
-0.6% | |||||||
Natural gas (MMcf) |
9,890 |
9,690 |
200 |
2.1% | |||||||
Total oil and natural gas (MBoe) (1) |
3,921 |
3,901 |
20 |
0.5% | |||||||
Total oil and natural gas (MMcfe) (1) |
23,524 |
23,404 |
120 |
0.5% | |||||||
Average daily equivalent sales (MBoe/d) |
43.1 |
42.9 |
0.2 |
0.5% | |||||||
Average daily equivalent sales (MMcfe/d) |
258.5 |
257.2 |
1.3 |
0.5% | |||||||
Average realized sales prices: |
|||||||||||
Oil ($/Bbl) |
$ |
44.54 |
$ |
39.11 |
$ |
5.43 |
13.9% | ||||
NGLs ($/Bbl) |
20.15 |
15.56 |
4.59 |
29.5% | |||||||
Oil and NGLs ($/Bbl) |
40.78 |
34.46 |
6.32 |
18.3% | |||||||
Natural gas ($/Mcf) |
2.96 |
2.05 |
0.91 |
44.4% | |||||||
Barrel of oil equivalent ($/Boe) |
31.10 |
25.28 |
5.82 |
23.0% | |||||||
Natural gas equivalent ($/Mcfe) |
5.18 |
4.21 |
0.97 |
23.0% | |||||||
Average per Boe ($/Boe): |
|||||||||||
Lease operating expenses |
$ |
8.04 |
$ |
9.39 |
$ |
(1.35) |
-14.4% | ||||
Gathering and transportation costs and production taxes |
1.47 |
1.74 |
(0.27) |
-15.5% | |||||||
Depreciation, depletion, amortization and accretion |
10.29 |
14.74 |
(4.45) |
-30.2% | |||||||
General and administrative expenses |
4.20 |
4.16 |
0.04 |
1.0% | |||||||
Average per Mcfe ($/Mcfe): |
|||||||||||
Lease operating expenses |
$ |
1.34 |
$ |
1.56 |
$ |
(0.22) |
-14.1% | ||||
Gathering and transportation costs and production taxes |
0.25 |
0.29 |
(0.04) |
-13.8% | |||||||
Depreciation, depletion, amortization and accretion |
1.72 |
2.46 |
(0.74) |
-30.1% | |||||||
General and administrative expenses |
0.70 |
0.69 |
0.01 |
1.4% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. | |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||||||
Condensed Operating Data | |||||||||||
(Unaudited) | |||||||||||
Six Months Ended |
|||||||||||
June 30, |
Variance | ||||||||||
2017 |
2016 |
Variance |
Percentage(2) | ||||||||
Net sales volumes: |
|||||||||||
Oil (MBbls) |
3,728 |
3,740 |
(12) |
-0.3% | |||||||
NGL (MBbls) |
725 |
809 |
(84) |
-10.4% | |||||||
Oil and NGLs (MBbls) |
4,452 |
4,549 |
(97) |
-2.1% | |||||||
Natural gas (MMcf) |
19,875 |
19,761 |
114 |
0.6% | |||||||
Total oil and natural gas (MBoe) (1) |
7,765 |
7,843 |
(78) |
-1.0% | |||||||
Total oil and natural gas (MMcfe) (1) |
46,589 |
47,055 |
(466) |
-1.0% | |||||||
Average daily equivalent sales (MBoe/d) |
42.9 |
43.1 |
(0.2) |
-0.5% | |||||||
Average daily equivalent sales (MMcfe/d) |
257.4 |
258.5 |
(1.1) |
-0.5% | |||||||
Average realized sales prices: |
|||||||||||
Oil ($/Bbl) |
$ |
45.76 |
$ |
32.80 |
$ |
12.96 |
39.5% | ||||
NGLs ($/Bbl) |
21.80 |
14.85 |
6.95 |
46.8% | |||||||
Oil and NGLs ($/Bbl) |
41.86 |
29.61 |
12.25 |
41.4% | |||||||
Natural gas ($/Mcf) |
2.97 |
2.03 |
0.94 |
46.3% | |||||||
Barrel of oil equivalent ($/Boe) |
31.61 |
22.29 |
9.32 |
41.8% | |||||||
Natural gas equivalent ($/Mcfe) |
5.27 |
3.71 |
1.56 |
42.0% | |||||||
Average per Boe ($/Boe): |
|||||||||||
Lease operating expenses |
$ |
9.23 |
$ |
10.34 |
$ |
(1.11) |
-10.7% | ||||
Gathering and transportation costs and production taxes |
1.61 |
1.58 |
0.03 |
1.9% | |||||||
Depreciation, depletion, amortization and accretion |
10.35 |
15.46 |
(5.11) |
-33.1% | |||||||
General and administrative expenses |
3.83 |
4.17 |
(0.34) |
-8.2% | |||||||
Average per Mcfe ($/Mcfe): |
|||||||||||
Lease operating expenses |
$ |
1.54 |
$ |
1.72 |
$ |
(0.18) |
-10.5% | ||||
Gathering and transportation costs and production taxes |
0.27 |
0.26 |
0.01 |
3.8% | |||||||
Depreciation, depletion, amortization and accretion |
1.72 |
2.58 |
(0.86) |
-33.3% | |||||||
General and administrative expenses |
0.64 |
0.69 |
(0.05) |
-7.2% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. | |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||
Condensed Consolidated Balance Sheets | ||||||
(Unaudited) | ||||||
June 30, |
December 31, | |||||
2017 |
2016 | |||||
(In thousands, except | ||||||
share data) | ||||||
Assets |
||||||
Current assets: |
||||||
Cash and cash equivalents |
$ |
72,320 |
$ |
70,236 | ||
Receivables: |
||||||
Oil and natural gas sales |
39,397 |
43,073 | ||||
Joint interest |
19,920 |
21,885 | ||||
Insurance reimbursement |
- |
30,100 | ||||
Income Taxes |
12,027 |
11,943 | ||||
Total receivables |
71,344 |
107,001 | ||||
Prepaid expenses and other assets |
21,944 |
14,504 | ||||
Total current assets |
165,608 |
191,741 | ||||
Total property and equipment |
8,028,825 |
7,953,402 | ||||
Less accumulated depreciation, depletion and amortization |
7,478,144 |
7,406,349 | ||||
Net property and equipment |
550,681 |
547,053 | ||||
Restricted deposits for asset retirement obligations |
28,712 |
27,371 | ||||
Income tax receivables |
68,974 |
52,097 | ||||
Escrow deposit - Apache lawsuit |
49,500 |
- | ||||
Other assets |
11,496 |
11,464 | ||||
Total assets |
$ |
874,971 |
$ |
829,726 | ||
Liabilities and Shareholders' Deficit |
||||||
Current liabilities: |
||||||
Accounts payable |
$ |
58,283 |
$ |
81,039 | ||
Undistributed oil and natural gas proceeds |
21,270 |
26,254 | ||||
Asset retirement obligations |
52,432 |
78,264 | ||||
Long-term debt |
11,147 |
8,272 | ||||
Accrued liabilities |
13,122 |
9,200 | ||||
Total current liabilities |
156,254 |
203,029 | ||||
Long-term debt: |
||||||
Principal |
873,733 |
873,733 | ||||
Carrying value adjustments |
110,604 |
138,722 | ||||
Long-term debt, less current portion - carrying value |
984,337 |
1,012,455 | ||||
Asset retirement obligations, less current portion |
265,428 |
256,174 | ||||
Apache lawsuit liability |
49,500 |
- | ||||
Other liabilities |
17,409 |
17,105 | ||||
Commitments and contingencies |
- |
- | ||||
Shareholders' deficit: |
||||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 140,690,917 |
||||||
issued and 137,821,744 outstanding at June 30, 2017; 140,543,545 issued and |
||||||
137,674,372 outstanding at December 31, 2016 |
1 |
1 | ||||
Additional paid-in capital |
543,439 |
539,973 | ||||
Retained earnings (deficit) |
(1,117,230) |
(1,174,844) | ||||
Treasury stock, at cost |
(24,167) |
(24,167) | ||||
Total shareholders' deficit |
(597,957) |
(659,037) | ||||
Total liabilities and shareholders' deficit |
$ |
874,971 |
$ |
829,726 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Statements of Cash Flows | |||||||
(Unaudited) | |||||||
Six Months Ended |
|||||||
June 30, |
|||||||
2017 |
2016 |
||||||
(In thousands) |
|||||||
Operating activities: |
|||||||
Net Income (loss) |
$ |
57,614 |
$ |
(311,431) |
|||
Adjustments to reconcile net loss to net cash provided by (used in) operating activities: |
|||||||
Depreciation, depletion, amortization and accretion |
80,354 |
121,226 |
|||||
Ceiling test write-down of oil and natural gas properties |
- |
221,151 |
|||||
Gain on exchange of debt |
(7,811) |
- |
|||||
Debt issuance costs write-down/amortization of debt items |
836 |
1,880 |
|||||
Share-based compensation |
3,466 |
5,121 |
|||||
Derivative (gain) loss |
(7,644) |
2,449 |
|||||
Cash receipts on derivative settlements |
2,208 |
4,746 |
|||||
Deferred income taxes |
212 |
19,285 |
|||||
Changes in operating assets and liabilities: |
|||||||
Oil and natural gas receivables |
3,675 |
1,226 |
|||||
Joint interest receivables |
1,965 |
1,763 |
|||||
Insurance reimbursements |
30,100 |
- |
|||||
Income taxes |
(16,960) |
(57,931) |
|||||
Prepaid expenses and other assets |
(3,575) |
(10,365) |
|||||
Escrow deposit - Apache lawsuit |
(49,500) |
- |
|||||
Asset retirement obligation settlements |
(36,021) |
(25,156) |
|||||
Accounts payable, accrued liabilities and other |
6,666 |
14,767 |
|||||
Net cash provided by (used in) operating activities |
65,585 |
(11,269) |
|||||
Investing activities: |
|||||||
Investment in oil and natural gas properties and equipment |
(43,800) |
(17,712) |
|||||
Changes in operating assets and liabilities associated with investing activities |
(827) |
(34,122) |
|||||
Proceeds from sales of assets |
- |
1,500 |
|||||
Purchases of furniture, fixtures and other |
(853) |
(70) |
|||||
Net cash used in investing activities |
(45,480) |
(50,404) |
|||||
Financing activities: |
|||||||
Borrowings of long-term debt - revolving bank credit facility |
- |
340,000 |
|||||
Repayments of long-term debt - revolving bank credit facility |
- |
(192,000) |
|||||
Payment of interest on 1.5 Lien Term Loan |
(4,113) |
- |
|||||
Payment of interest on 2nd Lien PIK Toggle Notes |
(7,335) |
- |
|||||
Payment of interest on 3rd Lien PIK Toggle Notes |
(6,201) |
- |
|||||
Other |
(372) |
83 |
|||||
Net cash provided by (used in) financing activities |
(18,021) |
148,083 |
|||||
Increase in cash and cash equivalents |
2,084 |
86,410 |
|||||
Cash and cash equivalents, beginning of period |
70,236 |
85,414 |
|||||
Cash and cash equivalents, end of period |
$ |
72,320 |
$ |
171,824 |
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 (Loss) to Net Income (Loss) Excluding Special Items
"Net Income (Loss) Excluding Special Items" does not include the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, write-down of debt issue costs, ceiling test write-down of oil and natural gas properties, gain on exchange of debt, Apache lawsuit, East Cameron 321 settlement, civil penalties, and associated income tax adjustments. 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 |
Six Months Ended |
||||||||||||||
June 30, |
June 30, |
||||||||||||||
2017 |
2016 |
2017 |
2016 |
||||||||||||
(In thousands, except per share amounts) | |||||||||||||||
(Unaudited) | |||||||||||||||
Net income (loss) |
$ |
33,315 |
$ |
(120,922) |
$ |
57,614 |
$ |
(311,431) |
|||||||
Unrealized commodity derivative (gain) loss |
(2,194) |
5,583 |
(5,436) |
7,195 |
|||||||||||
Default in payment by joint interest partners |
270 |
140 |
475 |
1,402 |
|||||||||||
Write-down debt issue costs |
- |
- |
- |
1,368 |
|||||||||||
Ceiling test write-down of oil and natural gas properties |
- |
104,592 |
- |
221,151 |
|||||||||||
Gain on exchange of debt |
(8,056) |
- |
(7,811) |
- |
|||||||||||
Apache lawsuit |
6,285 |
- |
6,285 |
- |
|||||||||||
EC 321 settlement |
(1,109) |
- |
(1,109) |
- |
|||||||||||
Civil Penalties |
1,289 |
- |
1,820 |
- |
|||||||||||
Income tax adjustment |
1,297 |
(25,152) |
2,328 |
(26,578) |
|||||||||||
Net income (loss) excluding special items |
$ |
31,097 |
$ |
(35,759) |
$ |
54,166 |
$ |
(106,893) |
|||||||
Basic and diluted income (loss) per common share, excluding special items |
$ |
0.22 |
$ |
(0.47) |
$ |
0.38 |
$ |
(1.40) |
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Reconciliation of Net Income (Loss) to Adjusted EBITDA
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, gain on exchange of debt, Apache lawsuit, East Cameron 321 settlement, civil penalties, and write-down of debt issue costs. 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 (loss), 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 (loss) to EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Three Months Ended |
Six Months Ended |
||||||||||||||
June 30, |
June 30, |
||||||||||||||
2017 |
2016 |
2017 |
2016 |
||||||||||||
(In thousands) | |||||||||||||||
(Unaudited) | |||||||||||||||
Net income (loss) |
$ |
33,315 |
$ |
(120,922) |
$ |
57,614 |
$ |
(311,431) |
|||||||
Income tax expense (benefit) |
(8,975) |
(35,722) |
(16,563) |
(40,604) |
|||||||||||
Net interest expense |
11,429 |
29,647 |
22,718 |
57,056 |
|||||||||||
Depreciation, depletion, amortization and accretion |
40,364 |
57,493 |
80,354 |
121,226 |
|||||||||||
Ceiling test write-down of oil and natural gas properties |
- |
104,592 |
- |
221,151 |
|||||||||||
EBITDA |
76,133 |
35,088 |
144,123 |
47,398 |
|||||||||||
Adjustments: |
|||||||||||||||
Unrealized commodity derivative (gain) loss |
(2,194) |
5,583 |
(5,436) |
7,195 |
|||||||||||
Default in payment by joint interest partners |
270 |
140 |
475 |
1,402 |
|||||||||||
Gain on exchange of debt |
(8,056) |
- |
(7,811) |
- |
|||||||||||
Apache lawsuit |
6,285 |
- |
6,285 |
- |
|||||||||||
EC 321 settlement |
(1,109) |
- |
(1,109) |
- |
|||||||||||
Civil Penalties |
1,289 |
- |
1,820 |
- |
|||||||||||
Write-down debt issue costs |
- |
- |
- |
1,368 |
|||||||||||
Adjusted EBITDA |
$ |
72,618 |
$ |
40,811 |
$ |
138,347 |
$ |
57,363 |
|||||||
Adjusted EBITDA Margin |
59% |
41% |
56% |
32% |
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-second-quarter-2017-operational-and-financial-results-300499480.html
SOURCE W&T Offshore, Inc.
HOUSTON, July 18, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its second quarter 2017 financial and operational results after the market closes on Thursday, August 3, 2017. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Friday, August 4 at 10:00 a.m. Eastern Time (9:00 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through August 11, 2017 by dialing 1-201-612-7415 and using the passcode 13666117. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | |
713-529-6600 |
713-624-7326 |
View original content:http://www.prnewswire.com/news-releases/wt-offshore-announces-second-quarter-2017-financial-and-operational-results-release-and-conference-call-schedule-300490045.html
SOURCE W&T Offshore, Inc.
HOUSTON, June 1, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported that it has received a final trial court judgment from the U.S. District Court for the Southern District of Texas directing the company to pay Apache Corp. $43.2 million, plus $4.4 million in prejudgment interest, attorney's fees and costs assessed in the judgment.
The judgment stems from a previously disclosed lawsuit that Apache filed in December 2014 regarding a dispute about Apache's use of drilling rigs instead of a previously contracted intervention vessel for the plugging and abandonment of three deepwater wells in the Mississippi Canyon area of the Gulf of Mexico. W&T contends that the costs to use the drilling rigs were unnecessary and unreasonable but that Apache chose to use the rigs without W&T's consent because they otherwise would have been idle at Apache's expense. W&T believes the use of the rigs was in bad faith, as found by the jury, and in breach of the applicable joint operating agreement, particularly since another vessel had been contracted by Apache for the abandonment a year in advance. W&T had previously paid $24.9 million as an undisputed amount for the plug and abandonment work.
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "W&T is disappointed in the judgment signed by the district court and believes that it is contrary to the applicable law given the jury's finding in October 2016 that Apache acted in bad faith. W&T is considering its options, including post judgment motions and appeal."
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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, 2016 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, May 3, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its first quarter 2017 operational and financial results. Some of the key items for the first quarter of 2017 and subsequent period include:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "Our first quarter 2017 results greatly improved over the same time last year as we benefited from higher commodity prices and lower expenses, allowing us to continue to generate net income and solid free cash flow. Production was up about 6% sequentially and down only 2.5% from a year ago, on very modest drilling activity, with our continuing success at Mahogany whereby we can put successful wells on line quickly increasing production along with our beneficial workover and recompletion program. Additionally, unlike many shale wells, the Gulf of Mexico wells don't typically exhibit as steep of a decline curve and thereby contribute strong production rates well past the initial production phase by comparison.
"Our Mahogany field continues to be a stellar performer as we placed the A-18 well on production in January. That well continues to produce at about 5,000 Boe per day. We finished a bypass completion at our A-16 location on the last day of March and that well is producing almost 2,000 Boe per day currently. We have additional activity planned for the Mahogany field in 2017 including at least one exploration well and one development sidetrack well.
"As we have previously indicated, our 2017 capital expenditure program is flexible and subject to change as we continue to focus on identifying and pursuing the best opportunities. Recently, we added the B-5 well at Ship Shoal 300 to this year's drilling plan and we have received all necessary partner approvals. The well will be drilled from an existing platform in the field and drilling should commence in the middle of 2017. This represents a low risk stacked pay opportunity that could add new production quickly. Assuming success, another drilling location from the platform could be added to the program. New seismic indicates a strong amplitude feature and multiple pay horizons. Like other projects in our 2017 capital program, the SS 300 B-5 well is expected to achieve an internal rate of return in excess of 75%. Based on the current performance of the SS 349 A-18 and A-16 wells, we expect these wells to achieve rates of return in excess of 100%," added Mr. Krohn.
Production, Revenues and Price: Total production was 3.8 million barrels of oil equivalent ("MMBoe") in the first quarter of 2017, down 2.5% from the first quarter of 2016. Production was lower compared to the first quarter of 2016 due to natural production declines, well performance, and platform maintenance. This was partially offset by new oil production activity at certain fields within the last year, including Ewing Bank 910, Viosca Knoll 823 ("Virgo"), East Cameron 321, Garden Banks 302 ("PowerPlay") and Main Pass 108 fields.
Revenues for the first quarter of 2017 increased 60% to $124.4 million compared to $77.7 million in the first quarter of 2016. The increase in revenues was due to a 66% increase in realized commodity prices, partially offset by a 2.5% decrease in production, the majority of which was attributable to downtime for platform maintenance at our Tahoe field. We sold 42,712 Boe per day at an average realized sales price of $32.12 per Boe compared to 43,317 Boe per day sold at an average realized sales price of $19.33 per Boe in the first quarter of 2016.
Lease Operating Expenses: LOE -- which includes base lease operating expenses, insurance premiums, workovers, and facilities maintenance -- decreased $4.3 million, to $40.2 million in the first quarter of 2017 compared to the first quarter of 2016. On a per Boe basis, LOE decreased to $10.45 per Boe in the first quarter of 2017, a 7.4% reduction compared to $11.28 per Boe in the first quarter of 2016. LOE decreased primarily due to lower costs from service providers, lower insurance premiums and optimization efforts at reducing our lease operating costs. These reductions were partially offset by higher workover costs of $2.6 million due to an increase in activities.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for asset retirement obligations ("ARO"), decreased to $10.40 per Boe for the first quarter of 2017 from $16.17 per Boe for the first quarter of 2016. On a nominal basis, DD&A decreased $23.7 million to $40.0 million for the first quarter of 2017 from $63.7 million for the first quarter of 2016 primarily due to a decrease in the DD&A rate per Boe. DD&A on a per Boe and nominal basis decreased primarily due to prior-period ceiling test write-downs.
General and Administrative Expenses ("G&A"): G&A decreased $3.2 million, or 19% to $13.3 million for the first quarter of 2017 compared to the first quarter of 2016. The decrease was primarily due to reduced headcount related expenses (salaries and benefits along with reduced contractor headcount), lower legal costs, and decreased medical claims.
Interest expense: Interest expense, net of capitalized interest, declined $16.2 million to $11.3 million in the first quarter of 2017, compared to $27.5 million in the first quarter of 2016. The decrease was primarily due to an exchange transaction that was completed on September 7, 2016, when we exchanged $710.2 million of our unsecured senior notes for $301.8 million of new secured notes and 60 million shares of our common stock. Also, there were no borrowings outstanding under our revolving bank credit facility during the first quarter of 2017.
Income Tax: Our income tax benefit for the three months ended March 31, 2017 and 2016 was $7.6 million and $4.9 million, respectively. Our annualized effective tax rate for both periods was not meaningful. An income tax benefit was recorded in each period presented related to net operating loss ("NOL") carryback claims for 2017 and 2016 carried back to 2007 and 2006, respectively.
As of March 31, 2017, the balance sheet reflects a current income tax receivable of $11.9 million and non-current income tax receivables of $59.8 million. The current income tax receivable primarily relates to our NOL claim for 2016 carried back to 2006. The non-current income tax receivables relate to our NOL claims that were carried back to earlier years that are expected to be realized in 2018.
Net Income (Loss) & Earnings (Loss) Per Share: We reported net income for the first quarter of 2017 of $24.3 million or $0.17 per common share. Excluding special items, our adjusted net income was $22.8 million and our earnings were $0.16 per share. This compares to a first quarter 2016 reported net loss of ($190.5) million, or ($2.49) per common share; excluding special items (including a ceiling test write-down of oil and natural gas properties) adjusted net loss would have been ($72.7) million, or ($0.95) per share. Sequentially, net income, excluding special items, increased $15.1 million or $0.10 per share. (See the "Reconciliation of Net Income (Loss) to Net Income (Loss) 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: 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.
Net cash provided by operating activities in the first three months of 2017 was $81.2 million compared to $29.7 million for the same period in 2016.
Cash flows from operating activities before changes in working capital, insurance reimbursements and ARO settlements were $63.5 million in 2017, compared to a negative $9.6 million generated over the same period in 2016. Other items affecting operating cash flows for the three months ended March 31, 2017 were insurance reimbursements of $30.1 million and changes in receivables, accounts payable and accrued liabilities of $2.2 million, partially offset by ARO settlements of $14.5 million.
Adjusted EBITDA for the first quarter of 2017 was $65.2 million, up $48.4 million over the same period in 2016. Our Adjusted EBITDA margin was 52% in the first quarter of 2017, compared to 21% in the first quarter of 2016.
Liquidity: At March 31, 2017, our total liquidity was $275.6 million, consisting of a cash balance of $126.1 million and $149.5 million of availability under our $150 million revolving bank credit facility, up from a cash balance of $70.2 million and total liquidity of $219.7 million at December 31, 2016.
Capital Expenditures: Our capital expenditures for oil and gas properties on an accrual basis for the first quarter of 2017 were $23.3 million ($22.2 million on a cash basis) compared to $12.9 million ($33.6 million on a cash basis) for the first quarter of 2016. In the first quarter of 2017 our capital expenditures were primarily directed at completion operations at the Ship Shoal 349 ("Mahogany") A-18 well and drilling and completion operations at the SS 349 A-16 bypass. The remainder of the expenditures was associated with recompletions, development activities and seismic.
Our capital expenditures for 2017 are currently estimated at $125.0 million. Our plug and abandonment activities for 2017 are currently estimated at approximately $78.3 million. Capital expenditures and abandonment activities are expected to be funded with cash on hand and cash flow from operating activities.
BOEM FINANCIAL ASSURANCES UPDATE
We are in final stages of resolving a matter with the BOEM that began over a year ago with its demand that W&T secure financial assurances (such as supplemental bonding) in the aggregate of $260.8 million. We recently received a letter from the BOEM that indicated that in order for the BOEM to rescind the order, we must first satisfy our financial assurance requirement related to "sole liability" properties. We believe that we can satisfy our obligation under the most recent BOEM request for financial assurance of sole liability properties and we will request that the previous orders pertaining to the $260.8 million of financial assurances be rescinded.
OPERATIONS UPDATE
We currently have one rig operating in the Gulf of Mexico which is at Ship Shoal 349 drilling the A-8 bypass.
Ship Shoal 349 A-18 "Mahogany" (100% WI, operated, shelf):
During the first quarter, our Ship Shoal 349 ("Mahogany") A-18 well was placed on production and is currently producing about 5,000 Boe per day and is 75% oil. The rig then conducted a bypass operation on the A-16 well targeting the 'P' sand. The A-16 well was placed on production in mid-April and is currently producing almost 1,950 Boe per day and is 82% oil. The rig is currently drilling the A-8 bypass well to target a crestal 'P' Sand location. This well is expected to reach total depth within the next month or so. Following the A-8 well, we will most likely drill the A-17 well, which would target the deep 'T' Sand as an extension of the 'T' reservoir. Following that well we plan to drill a sidetrack well at the A-5 location targeting the 'Q' and 'P' Sands.
Ship Shoal 300 B-5 (80% WI, operated, shelf):
We recently added the SS 300 B-5 well to our 2017 drilling program and expect to spud the well in the middle of this year. SS 300 is a proven oil field with an existing platform from which to drill the B-5 well. All necessary partner approvals have been received. Assuming the well is successful, we could possibly add a second well to further increase reserves and value.
We believe that this well represents a low risk opportunity with stacked pay potential. New seismic indicates a strong amplitude feature and multiple pay horizons. Like other projects in our 2017 capital program, the SS 300 B-5 well is expected to achieve a rate of return in excess of 75%.
Ewing Bank 910 (36% - 50% WI, operated, deepwater)
Two wells are planned in our Ewing Bank 910 field this year which include the South Timbalier 311 A-2 and A-3 sidetrack wells. The first well is expected to spud in the middle of 2017 with the next well to follow shortly thereafter, but should be completed in 2018. We view both of these wells to be low risk exploration with stacked pay sands. If successful, these wells can be brought on line quickly via existing infrastructure and pipelines.
Well Recompletions and Workovers: We recently recompleted the High Island 21 A-1 well as a dual completion in the High Island 22 field. That work along with returning the High Island 22 platform to service increased production to 5.6 MMcf per day. Recompletion operations have just concluded at South Timbalier 229 A-4 with the well reaching an initial production rate in excess of 500 Boe per day.
Second Quarter and Full Year 2017 Outlook:
Our guidance for the second quarter and full year 2017 is provided in the table below and 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."
Second Quarter |
Prior Full Year |
Revised Full Year | |||
Production |
2017 |
2017 |
2017 | ||
Oil and NGL's (MMBbls) |
2.1 - 2.4 |
8.3 - 9.2 |
8.7 - 9.7 | ||
Natural Gas (Bcf) |
9.5 - 10.5 |
41.4 - 45.7 |
38.9 - 42.9 | ||
Total (Bcf) |
22.4 - 24.8 |
91.1 - 100.6 |
91.2 - 100.8 | ||
Total (MMBoe) |
3.7 - 4.1 |
15.2 - 16.8 |
15.2 - 16.8 | ||
Operating Expenses |
Second Quarter |
Prior Full Year |
Revised Full Year | ||
($ in millions) |
2017 |
2017 |
2017 | ||
Lease operating expenses |
$45 - $50 |
$167 - $185 |
$161 - $177 | ||
Gathering, transportation & |
|||||
production taxes |
$6.6 - $7.2 |
$23 - $26 |
$26 - $29 | ||
General and administrative |
$15 - $16 |
$57 - $63 |
$58 - $64 | ||
Income tax rate benefit |
24% |
46% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, May 4, 2017, at 9:30 a.m. Eastern 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. An updated investor presentation can be accessed from the Company's website. A replay of the conference call will be available approximately two hours after the end of the call until May 11, 2017, and may be accessed by calling 201-612-7415 and using the passcode13660473#.
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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, 2016 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 | ||||||||
Condensed Consolidated Statements of Income (Loss) | ||||||||
(Unaudited) | ||||||||
Three Months Ended |
||||||||
March 31, |
||||||||
2017 |
2016 |
|||||||
(In thousands, except per share data) |
||||||||
Revenues |
$ |
124,393 |
$ |
77,715 |
||||
Operating costs and expenses: |
||||||||
Lease operating expenses |
40,164 |
44,469 |
||||||
Gathering, transportation costs and production taxes |
6,724 |
5,618 |
||||||
Depreciation, depletion, amortization and accretion |
39,990 |
63,733 |
||||||
Ceiling test write-down of oil and natural gas properties |
- |
116,559 |
||||||
General and administrative expenses |
13,274 |
16,443 |
||||||
Derivative gain |
(3,955) |
(2,493) |
||||||
Total costs and expenses |
96,197 |
244,329 |
||||||
Operating income (loss) |
28,196 |
(166,614) |
||||||
Interest expense, net of amounts capitalized |
11,294 |
27,471 |
||||||
Other expense, net |
191 |
1,306 |
||||||
Income (loss) before income tax benefit |
16,711 |
(195,391) |
||||||
Income tax benefit |
(7,588) |
(4,882) |
||||||
Net income (loss) |
$ |
24,299 |
$ |
(190,509) |
||||
Basic and diluted earnings (loss) per common share |
$ |
0.17 |
$ |
(2.49) |
||||
Weighted average common shares outstanding |
137,513 |
76,428 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Three Months Ended |
||||||||||||
March 31, |
Variance | |||||||||||
2017 |
2016 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
1,805 |
1,906 |
(101) |
-5.3% | ||||||||
NGL (MBbls) |
374 |
358 |
16 |
4.5% | ||||||||
Oil and NGLs (MBbls) |
2,180 |
2,263 |
(83) |
-3.7% | ||||||||
Natural gas (MMcf) |
9,985 |
10,071 |
(86) |
-0.9% | ||||||||
Total oil and natural gas (MBoe) (1) |
3,844 |
3,942 |
(98) |
-2.5% | ||||||||
Total oil and natural gas (MMcfe) (1) |
23,065 |
23,651 |
(586) |
-2.5% | ||||||||
Average daily equivalent sales (MBoe/d) |
42.7 |
43.3 |
(0.6) |
-1.5% | ||||||||
Average daily equivalent sales (MMcfe/d) |
256.3 |
259.9 |
(3.6) |
-1.4% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
47.06 |
$ |
26.73 |
$ |
20.33 |
76.1% | |||||
NGLs ($/Bbl) |
23.34 |
13.96 |
9.38 |
67.2% | ||||||||
Oil and NGLs ($/Bbl) |
42.99 |
24.71 |
18.28 |
74.0% | ||||||||
Natural gas ($/Mcf) |
2.98 |
2.01 |
0.97 |
48.3% | ||||||||
Barrel of oil equivalent ($/Boe) |
32.12 |
19.33 |
12.79 |
66.2% | ||||||||
Natural gas equivalent ($/Mcfe) |
5.35 |
3.22 |
2.13 |
66.1% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
10.45 |
$ |
11.28 |
$ |
(0.83) |
-7.4% | |||||
Gathering and transportation costs and production taxes |
1.75 |
1.43 |
0.32 |
22.4% | ||||||||
Depreciation, depletion, amortization and accretion |
10.40 |
16.17 |
(5.77) |
-35.7% | ||||||||
General and administrative expenses |
3.45 |
4.17 |
(0.72) |
-17.3% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.74 |
$ |
1.88 |
$ |
(0.14) |
-7.4% | |||||
Gathering and transportation costs and production taxes |
0.29 |
0.24 |
0.05 |
20.8% | ||||||||
Depreciation, depletion, amortization and accretion |
1.73 |
2.69 |
(0.96) |
-35.7% | ||||||||
General and administrative expenses |
0.58 |
0.70 |
(0.12) |
-17.1% |
(1) |
MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) |
Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Balance Sheets | |||||||
(Unaudited) | |||||||
March 31, |
December 31, | ||||||
2017 |
2016 | ||||||
(In thousands, except | |||||||
share data) | |||||||
Assets |
|||||||
Current assets: |
|||||||
Cash and cash equivalents |
$ |
126,095 |
$ |
70,236 | |||
Receivables: |
|||||||
Oil and natural gas sales |
44,954 |
43,073 | |||||
Joint interest |
16,843 |
21,885 | |||||
Insurance reimbursement |
- |
30,100 | |||||
Income Taxes |
11,943 |
11,943 | |||||
Total receivables |
73,740 |
107,001 | |||||
Prepaid expenses and other assets |
17,135 |
14,504 | |||||
Total current assets |
216,970 |
191,741 | |||||
Total property and equipment |
7,980,252 |
7,953,402 | |||||
Less accumulated depreciation, depletion and amortization |
7,442,138 |
7,406,349 | |||||
Net property and equipment |
538,114 |
547,053 | |||||
Restricted deposits for asset retirement obligations |
28,224 |
27,371 | |||||
Income tax receivables |
59,789 |
52,097 | |||||
Other assets |
11,403 |
11,464 | |||||
Total assets |
$ |
854,500 |
$ |
829,726 | |||
Liabilities and Shareholders' Deficit |
|||||||
Current liabilities: |
|||||||
Accounts payable |
$ |
81,398 |
$ |
81,039 | |||
Undistributed oil and natural gas proceeds |
22,366 |
26,254 | |||||
Asset retirement obligations |
66,150 |
78,264 | |||||
Long-term debt |
8,250 |
8,272 | |||||
Accrued liabilities |
20,536 |
9,200 | |||||
Total current liabilities |
198,700 |
203,029 | |||||
Long-term debt, less current portion - carrying value |
1,010,734 |
1,012,455 | |||||
Asset retirement obligations, less current portion |
260,650 |
256,174 | |||||
Other liabilities |
17,226 |
17,105 | |||||
Commitments and contingencies |
- |
- | |||||
Shareholders' deficit: |
|||||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 140,543,545 issued and 137,674,372 outstanding at March 31, 2017 and December 31, 2016 |
1 |
1 | |||||
Additional paid-in capital |
541,901 |
539,973 | |||||
Retained earnings (deficit) |
(1,150,545) |
(1,174,844) | |||||
Treasury stock, at cost |
(24,167) |
(24,167) | |||||
Total shareholders' deficit |
(632,810) |
(659,037) | |||||
Total liabilities and shareholders' deficit |
$ |
854,500 |
$ |
829,726 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||
Condensed Consolidated Statements of Cash Flows | ||||||||
(Unaudited) | ||||||||
Three Months Ended |
||||||||
March 31, |
||||||||
2017 |
2016 |
|||||||
(In thousands) |
||||||||
Operating activities: |
||||||||
Net income (loss) |
$ |
24,299 |
$ |
(190,509) |
||||
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |
||||||||
Depreciation, depletion, amortization and accretion |
39,990 |
63,733 |
||||||
Ceiling test write-down of oil and natural gas properties |
- |
116,559 |
||||||
Debt issuance costs write-down/amortization of debt items |
412 |
1,684 |
||||||
Share-based compensation |
1,928 |
2,536 |
||||||
Derivative gain |
(3,955) |
(2,493) |
||||||
Cash receipts on derivative settlements |
713 |
4,105 |
||||||
Deferred income taxes |
105 |
(4,882) |
||||||
Asset retirement obligation settlements |
(14,499) |
(3,180) |
||||||
Income taxes |
- |
(310) |
||||||
Changes in operating assets and liabilities |
32,190 |
42,466 |
||||||
Net cash provided by operating activities |
81,183 |
29,709 |
||||||
Investing activities: |
||||||||
Investment in oil and natural gas properties and equipment |
(23,338) |
(12,903) |
||||||
Changes in operating assets and liabilities associated with investing activities |
1,168 |
(20,680) |
||||||
Proceeds from sales of assets |
- |
1,000 |
||||||
Purchases of furniture, fixtures and other |
(853) |
- |
||||||
Net cash used in investing activities |
(23,023) |
(32,583) |
||||||
Financing activities: |
||||||||
Borrowings of long-term debt - revolving bank credit facility |
- |
340,000 |
||||||
Repayments of long-term debt - revolving bank credit facility |
- |
(52,000) |
||||||
Payment of interest on 1.5 Lien Term Loan |
(2,056) |
- |
||||||
Other |
(245) |
83 |
||||||
Net cash provided by (used in) financing activities |
(2,301) |
288,083 |
||||||
Increase in cash and cash equivalents |
55,859 |
285,209 |
||||||
Cash and cash equivalents, beginning of period |
70,236 |
85,414 |
||||||
Cash and cash equivalents, end of period |
$ |
126,095 |
$ |
370,623 |
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 (Loss) to Net Income (Loss) Excluding Special Items
"Net Income (Loss) Excluding Special Items" does not include the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, write-down of debt issue costs, ceiling test write-down of oil and natural gas properties, costs related to the exchange of debt, and associated income tax adjustments. 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.
Adjusted Net Income |
|||||||||
Three Months Ended |
|||||||||
March 31, |
|||||||||
2017 |
2016 |
||||||||
(In thousands, except per share amounts) |
|||||||||
(Unaudited) | |||||||||
Net income (loss) |
$ |
24,299 |
$ |
(190,509) |
|||||
Unrealized commodity derivative (gain) loss |
(3,242) |
1,612 |
|||||||
Default in payment by joint interest partners |
205 |
1,262 |
|||||||
Write-down debt issue costs |
- |
1,368 |
|||||||
Ceiling test write-down of oil and natural gas properties |
- |
116,559 |
|||||||
Costs related to the exchange of debt |
245 |
- |
|||||||
Income tax adjustment |
1,268 |
(3,020) |
|||||||
Net income (loss) excluding special items |
$ |
22,775 |
$ |
(72,728) |
|||||
Basic and diluted income (loss) per common share, excluding special items |
$ |
0.16 |
$ |
(0.95) |
|||||
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Reconciliation of Net Income (Loss) to Adjusted EBITDA
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, costs related to the exchange of debt, and write-down of debt issue costs. 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 (loss), 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 (loss) to EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Adjusted EBITDA |
|||||||||
Three Months Ended |
|||||||||
March 31, |
|||||||||
2017 |
2016 |
||||||||
(In thousands) |
|||||||||
(Unaudited) |
|||||||||
Net income (loss) |
$ |
24,299 |
$ |
(190,509) |
|||||
Income tax expense (benefit) |
(7,588) |
(4,882) |
|||||||
Net interest expense |
11,289 |
27,409 |
|||||||
Depreciation, depletion, amortization and accretion |
39,990 |
63,733 |
|||||||
Ceiling test write-down of oil and natural gas properties |
- |
116,559 |
|||||||
EBITDA |
67,990 |
12,310 |
|||||||
Adjustments: |
|||||||||
Unrealized commodity derivative (gain) loss |
(3,242) |
1,612 |
|||||||
Default in payment by joint interest partners |
205 |
1,262 |
|||||||
Costs related to the exchange of debt |
245 |
- |
|||||||
Write-down debt issue costs |
- |
1,368 |
|||||||
Adjusted EBITDA |
$ |
65,198 |
$ |
16,552 |
|||||
Adjusted EBITDA Margin |
52% |
21% |
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, April 20, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced the promotions of Janet Yang to Vice President, Corporate & Business Development and James Hersch to Vice President, Geosciences.
Tracy Krohn, W&T Offshore's Chairman and CEO, stated, "Both Janet and Jim have proven themselves to be of great value to W&T and we are looking forward to their continued contributions to our future success."
Janet Yang has been with W&T Offshore since 2008 and was most recently Director, Strategic Planning & Analysis, a position she has held since 2012. Ms. Yang has over 15 years of finance, investment and strategy experience in the energy industry. Prior to joining W&T, Ms. Yang held positions in research and investment analysis at BlackGold Capital, investment banking at Raymond James and energy trading at Allegheny Energy. Ms. Yang received a B.A. in Economics from Rice University and an M.B.A. with concentrations in Finance and Accounting from The University of Chicago Booth School of Business.
James Hersch has been W&T Offshore since 2010 and was most recently Director, Geosciences. Mr. Hersch has over 35 years of experience as a geologist and led exploration teams analyzing oil and gas producing basins around the world for large and small companies, including Exxon, Anadarko Petroleum and Century Petroleum. Immediately prior to joining W&T, he was the Principal and Founder of a private geological/geophysical consulting firm for international and domestic North America projects. Mr. Hersch is a licensed geologist and received a B.A. in Geology from Appalachian State University and an M.S. in Economic Geology from the University of Tennessee.
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, April 20, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its first quarter 2017 financial and operational results after the market closes on Wednesday, May 3. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Thursday, May 4 at 9:30 a.m. Eastern Time (8:30 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through May 11, 2017 by dialing 1-201-612-7415 and using the passcode 13660473. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, April 18, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced that Thomas F. Getten, Vice President, General Counsel and Secretary of W&T Offshore has retired and has been succeeded by Shahid A. Ghauri, who joined the Company in March 2017.
Tracy Krohn, W&T Offshore's Chairman and CEO, stated, "We appreciate Tom's guidance and dedication to W&T since he joined the Company in 2006. We wish him the best in his well-deserved retirement. We also welcome Shahid Ghauri to the W&T team and believe he will be a great asset to the company."
Previously, Mr. Ghauri served as a partner with Jones Walker, where he focused primarily on business and commercial transactions in the oil and gas sector. Prior to that, Mr. Ghauri was the Assistant General Counsel of BHP Billiton Petroleum, where he managed the legal team responsible for unconventional resource plays. Prior to joining BHP, he worked in private law practice as an oil and gas lawyer with top tier law firms. Before earning his J.D. from the University of Houston Law Center, he was employed as a wireline logging engineer for Schlumberger.
Mr. Ghauri also received a B.S. and M.S. in Petroleum Engineering from the University of Texas at Austin. He is a member of the State Bars of Texas and Pennsylvania, the Houston Producers' Forum, the Society of Petroleum Engineers and the Association of International Petroleum Negotiators.
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, March 29, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that the Company will be participating in the 2017 IPAA Oil & Gas Investment Symposium to be held April 3-4, 2017 in New York City.
Tracy Krohn, W&T Offshore's Chairman and CEO, is scheduled to make a presentation on Monday, April 3, at 8:45 a.m. Eastern Time (7:45 a.m. Central Time). The presentation will be broadcast over the Internet. The webcast link to the audio presentation and accompanying slides can be accessed live and for replay by visiting the investor relations section of the Company's website at www.wtoffshore.com.
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, March 10, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that the Company will be participating in the 29th Annual ROTH Conference to be held March 13-15, 2017 in Dana Point, California.
Tracy Krohn, W&T Offshore's Chairman and CEO, is scheduled to make a presentation on Tuesday, March 14, at 12:30 pm Pacific Time (3:30 p.m. Eastern Time). The presentation will be broadcast over the Internet. The webcast link to the audio presentation and accompanying slides can be accessed live and for replay by visiting the investor relations section of the Company's website at www.wtoffshore.com.
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, March 1, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its fourth quarter 2016 operational and financial results. Some of the key items for the fourth quarter of 2016 and subsequent period include:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "With higher commodity prices and significantly lower expenses, we achieved much improved operating margins and positive earnings in the fourth quarter. We are pleased to have met the challenges of 2016 and have exited the year on solid footing and with lower debt. Even with a greatly reduced capital expenditure plan, we limited the decline in production and kept proved reserves relatively flat on a SEC basis but had 102% reserve replacement rate on a year-end NYMEX basis. Although the value of our proved reserves declined based on backward looking SEC pricing, the value would have grown substantially based on NYMEX forward pricing as of the end of 2016.
"We are as enthusiastic as ever about the opportunities in the Gulf of Mexico and believe we are in a good position to take advantage of this prolific basin. We are entering 2017 with a lower cost structure and a capital program of profitable projects that should allow us to build cash. We expect to benefit from improved seismic technologies, lower operating costs and less competition in the Gulf. Assuming commodity prices continue to remain steady, our 2017 capital plan allocates approximately $125 million to projects that we believe provide a low-risk and high return in producing fields. These projects should yield moderate production growth in 2017 over 2016," added Mr. Krohn.
Production, Revenues and Price: Total production was 3.7 million barrels of oil equivalent ("MMBoe") in the fourth quarter of 2016, down 10% from the fourth quarter of 2015. Production was lower in the fourth quarter of 2016 compared to the fourth quarter of 2015 due to natural production declines, well performance, pipeline outages along with field and platform maintenance. This was partially offset by new oil production from the development of certain deepwater fields within the last year (Big Bend, Dantzler and EW 910).
Revenues for the fourth quarter of 2016 increased 11% to $115.2 million compared to $104.1 million in the fourth quarter of 2015. The increase in revenues was primarily due to a 24% increase in realized commodity prices, partially offset by a 10% decrease in production. We sold 40,300 Boe per day at an average realized sales price of $30.83 per Boe compared to 44,800 Boe per day sold at an average realized sales price of $24.84 per Boe in the fourth quarter of 2015.
Lease Operating Expenses: LOE, which includes base lease operating expenses, insurance premiums, workovers, and facilities maintenance, decreased $15.5 million, or 31%, to $33.8 million in the fourth quarter of 2016 compared to the fourth quarter of 2015. On a per Boe basis, LOE decreased to $9.12 per Boe in the fourth quarter of 2016, a 24% reduction compared to $11.96 per Boe in the fourth quarter of 2015. LOE decreased primarily due to lower costs from service providers, reduced workovers and facilities costs and optimization efforts at structurally reducing our lease operating costs. These reductions were partially offset by costs related to our new deepwater fields at Dantzler and Big Bend and lower production handling fees (cost offsets) at our Mississippi Canyon 243 field (Matterhorn).
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for ARO, decreased to $10.50 per Boe for the fourth quarter of 2016 from $16.49 per Boe for the fourth quarter of 2015. On a nominal basis, DD&A decreased $29.1 million to $38.9 million for the fourth quarter of 2016 from $67.9 million for the fourth quarter of 2015 due to a decrease in the DD&A rate per Boe and lower production volumes. DD&A on a per Boe and nominal basis decreased primarily due to prior period ceiling test write-downs, lower capital expenses and lower future development costs.
General and Administrative Expenses ("G&A"): G&A decreased $1.7 million, or 11% to $14.4 million for the fourth quarter of 2016 compared to the fourth quarter of 2015. The decrease was primarily due to reduced headcount related expense (salaries, benefits, and contractor expenses) and the suspension of certain employee benefits.
Interest expense: Interest expense incurred declined $15.3 million to $11.5 million in the fourth quarter of 2016, compared to $26.8 million in the fourth quarter of 2015. The decrease was primarily due to the completion of an exchange transaction that was completed on September 7, 2016 at which time we exchanged a significant portion of our Unsecured Senior Notes for secured notes and common stock. Average borrowings outstanding on our revolving bank credit facility were also lower in the 2016 period.
Income Tax: Our income tax expense for the fourth quarter of 2016 was $1.0 million and our effective tax rate was 5.8%. For the fourth quarter 2015, we reported an income tax benefit of $36.8 million and our effective tax rate was 41.6%. The effective tax rate differs from the federal statutory tax rate for both periods primarily due to adjustments recorded in our valuation allowance. As of December 31, 2016, we had current income tax receivables of $11.9 million and long-term income tax receivables of $52.1 million.
Net Income (Loss) & Earnings (Loss) Per Share: We reported net income for the fourth quarter of 2016 of $16.5 million or $0.12 per common share. Excluding special items, our adjusted net income would have been $7.7 million or $0.06 per share. This compares to a fourth quarter of 2015 reported net loss of ($51.6) million, or ($0.68) per common share and excluding special items (including a ceiling test write-down of oil and natural gas properties) an adjusted net loss of ($30.5) million, or ($0.40) per share. See the "Reconciliation of Net Income (Loss) to Net Loss 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: 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.
Net cash provided by operating activities in 2016 was $14.2 million compared to net cash provided by operating activities of $133.2 million for the same period in 2015.
Cash flows from operating activities, before changes in working capital and asset retirement obligations ("ARO") settlements, were $103.1 million in 2016, compared to $140.3 million generated over the same period in 2015. Other items affecting operating cash flows for 2016 were ARO settlements of $72.3 million and collateral deposits of $16.9 million.
Adjusted EBITDA for the fourth quarter of 2016 was $69.6 million, up from $41.1 million generated over the same period in 2015. Our Adjusted EBITDA margin was 60% in the fourth quarter of 2016, compared to 39% in the fourth quarter of 2015. For the full year of 2016, our Adjusted EBITDA was $179.1million and our Adjusted EBITDA margin was 45% compared to Adjusted EBITDA of $231.7 million and an Adjusted EBITDA margin of 46% for the full year 2015.
Liquidity: At December 31, 2016, our total liquidity was $219.7 million consisting of cash balances of $70.2 million and $149.5 million of availability under our $150 million revolving bank credit facility.
2016 Capital Expenditures Update: Our capital expenditures on an accrual basis for the full year of 2016 were $48.6 million ($83.8 million on a cash basis) compared to $230.2 million ($285.6 million on a cash basis) for the full year of 2015. In 2016 our capital expenditures were directed at drilling and the commencement of completion operations at the Ship Shoal 349 "Mahogany" A-18 well, completion activities of the Ewing Bank 954 A-8 well, recompletions at Virgo (VK 823) and Main Pass 69 and a new pipeline at East Cameron 321. The remainder of the expenditures was associated with other development activities and seismic.
Our capital expenditures for 2017 are currently estimated at $125 million. Our plug and abandonment activities for 2017 are currently estimated to total $78.3 million and are expected to be funded with cash on hand and cash flow from operating activities.
OPERATIONS UPDATE
Ship Shoal 349 A-18 "Mahogany" (100% WI, operated, shelf): The recently completed Ship Shoal 349 (Mahogany) A-18 well reached a production rate in February of 5,217 Boe per day (4,032 barrels of oil per day and 7.1 MMcf per day). Following the A-18 completion, the rig was moved to the A-16 location to conduct a sidetrack to the 'P' sand (additional behind pipe zones above the main 'P' sand target is expected) and is anticipated to produce at a gross rate of between 1,100 to 1,500 Boe per day. Following the A-16 sidetrack, several additional workovers, recompletions and new drill wells are being planned for the remainder of this year and next.
Well Recompletions and Workovers: Our plan for 2017 is to perform between 20 and 25 recompletions at a cost of approximately $26 million. We currently have a high impact recompletion operation underway at our High Island 21 field targeting various zones above the producing zone in the current wellbore. The recompletion is expected to produce at a gross rate of in excess of 1,000 Boe per day when completed in the first quarter of 2017. We hold a 100% working interest in the well.
First Quarter and Full Year 2017 Outlook: Our guidance for the first quarter and full year 2017 is provided in the financial section of the February Investor Relations presentation on our website.
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, March 2, 2017, at 9:30 a.m. Eastern 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 approximately two hours after the end of the call until March 9, 2017 and may be accessed by calling 201-612-7415 and using the passcode 13653711#.
Notice of Annual Meeting: The Company's 2017 Annual Meeting of Shareholders will be held at 8:00 a.m. Central Time on May 3, 2017, at the offices of the Company, Nine Greenway Plaza, Suite 300, Houston, Texas 77046. Shareholders of record at the close of business on March 13, 2017 are entitled to receive notice of the meeting and to vote the shares of W&T Offshore common stock they held as of that date.
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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, 2015 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 | ||||||||||||||
Condensed Consolidated Statements of Income (Loss) | ||||||||||||||
(Unaudited) | ||||||||||||||
Three Months Ended |
Twelve Months Ended | |||||||||||||
December 31, |
December 31, | |||||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||||
(In thousands, except per share data) | ||||||||||||||
Revenues |
$ |
115,213 |
$ |
104,064 |
$ |
399,986 |
$ |
507,265 | ||||||
Operating costs and expenses: |
||||||||||||||
Lease operating expenses |
33,788 |
49,265 |
152,399 |
192,765 | ||||||||||
Gathering, transportation costs and production taxes |
6,788 |
4,444 |
24,817 |
20,159 | ||||||||||
Depreciation, depletion, amortization and accretion |
38,883 |
67,933 |
211,609 |
394,071 | ||||||||||
Ceiling test write-down of oil and natural gas properties |
- |
32,388 |
279,063 |
987,238 | ||||||||||
General and administrative expenses |
14,370 |
16,072 |
59,740 |
73,110 | ||||||||||
Derivative (gain) loss |
65 |
(5,222) |
2,926 |
(14,375) | ||||||||||
Total costs and expenses |
93,894 |
164,880 |
730,554 |
1,652,968 | ||||||||||
Operating income (loss) |
21,319 |
(60,816) |
(330,568) |
(1,145,703) | ||||||||||
Interest expense: |
||||||||||||||
Incurred |
11,511 |
26,776 |
92,791 |
104,592 | ||||||||||
Capitalized |
- |
(1,246) |
(520) |
(7,256) | ||||||||||
Gain on exchange of debt |
(37) |
- |
123,923 |
- | ||||||||||
Other (income) expense, net |
(7,729) |
2,016 |
(6,520) |
4,663 | ||||||||||
Income (loss) before income tax expense (benefit) |
17,500 |
(88,362) |
(292,396) |
(1,247,702) | ||||||||||
Income tax expense (benefit) |
1,017 |
(36,756) |
(43,376) |
(202,984) | ||||||||||
Net income (loss) |
$ |
16,483 |
$ |
(51,606) |
$ |
(249,020) |
$ |
(1,044,718) | ||||||
Basic and diluted earnings (loss) per common share |
$ |
0.12 |
$ |
(0.68) |
$ |
(2.60) |
$ |
(13.76) | ||||||
Weighted average common shares outstanding |
137,031 |
76,024 |
95,644 |
75,931 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||
Condensed Operating Data | ||||||||||
(Unaudited) | ||||||||||
Three Months Ended |
||||||||||
December 31, |
Variance | |||||||||
2016 |
2015 |
Variance |
Percentage(2) | |||||||
Net sales volumes: |
||||||||||
Oil (MBbls) |
1,670 |
1,975 |
(305) |
-15.4% | ||||||
NGL (MBbls) |
361 |
363 |
(2) |
-0.6% | ||||||
Oil and NGLs (MBbls) |
2,031 |
2,339 |
(308) |
-13.2% | ||||||
Natural gas (MMcf) |
10,035 |
10,693 |
(658) |
-6.2% | ||||||
Total oil and natural gas (MBoe) (1) |
3,703 |
4,121 |
(418) |
-10.1% | ||||||
Total oil and natural gas (MMcfe) (1) |
22,220 |
24,724 |
(2,504) |
-10.1% | ||||||
Average daily equivalent sales (MBoe/d) |
40.3 |
44.8 |
(4.5) |
-10.1% | ||||||
Average daily equivalent sales (MMcfe/d) |
241.5 |
268.7 |
(27.2) |
-10.1% | ||||||
Average realized sales prices: |
||||||||||
Oil ($/Bbl) |
$ |
45.10 |
$ |
36.99 |
$ |
8.11 |
21.9% | |||
NGLs ($/Bbl) |
21.37 |
16.16 |
5.21 |
32.2% | ||||||
Oil and NGLs ($/Bbl) |
40.87 |
33.75 |
7.12 |
21.1% | ||||||
Natural gas ($/Mcf) |
3.11 |
2.19 |
0.92 |
42.0% | ||||||
Barrel of oil equivalent ($/Boe) |
30.83 |
24.84 |
5.99 |
24.1% | ||||||
Natural gas equivalent ($/Mcfe) |
5.14 |
4.14 |
1.00 |
24.2% | ||||||
Average per Boe ($/Boe): |
||||||||||
Lease operating expenses |
$ |
9.12 |
$ |
11.96 |
$ |
(2.84) |
-23.7% | |||
Gathering and transportation costs and production taxes |
1.83 |
1.08 |
0.75 |
69.4% | ||||||
Depreciation, depletion, amortization and accretion |
10.50 |
16.49 |
(5.99) |
-36.3% | ||||||
General and administrative expenses |
3.88 |
3.90 |
(0.02) |
-0.5% | ||||||
Average per Mcfe ($/Mcfe): |
||||||||||
Lease operating expenses |
$ |
1.52 |
$ |
1.99 |
$ |
(0.47) |
-23.6% | |||
Gathering and transportation costs and production taxes |
0.31 |
0.18 |
0.13 |
72.2% | ||||||
Depreciation, depletion, amortization and accretion |
1.75 |
2.75 |
(1.00) |
-36.4% | ||||||
General and administrative expenses |
0.65 |
0.65 |
- |
0.0% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly.
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data.
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Twelve Months Ended |
||||||||||||
December 31, |
Variance | |||||||||||
2016 |
2015 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
7,201 |
7,751 |
(550) |
-7.1% | ||||||||
NGL (MBbls) |
1,542 |
1,604 |
(62) |
-3.9% | ||||||||
Oil and NGLs (MBbls) |
8,743 |
9,355 |
(612) |
-6.5% | ||||||||
Natural gas (MMcf) |
39,731 |
46,163 |
(6,432) |
-13.9% | ||||||||
Total oil and natural gas (MBoe) (1) |
15,365 |
17,049 |
(1,684) |
-9.9% | ||||||||
Total oil and natural gas (MMcfe) (1) |
92,188 |
102,294 |
(10,106) |
-9.9% | ||||||||
Average daily equivalent sales (MBoe/d) |
42.0 |
46.7 |
(4.7) |
-10.1% | ||||||||
Average daily equivalent sales (MMcfe/d) |
251.9 |
280.3 |
(28.4) |
-10.1% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
37.35 |
$ |
45.05 |
$ |
(7.70) |
-17.1% | |||||
NGLs ($/Bbl) |
17.14 |
17.25 |
(0.11) |
-0.6% | ||||||||
Oil and NGLs ($/Bbl) |
33.79 |
40.28 |
(6.49) |
-16.1% | ||||||||
Natural gas ($/Mcf) |
2.53 |
2.67 |
(0.14) |
-5.2% | ||||||||
Barrel of oil equivalent ($/Boe) |
25.76 |
29.34 |
(3.58) |
-12.2% | ||||||||
Natural gas equivalent ($/Mcfe) |
4.29 |
4.89 |
(0.60) |
-12.3% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
9.92 |
$ |
11.31 |
$ |
(1.39) |
-12.3% | |||||
Gathering and transportation costs and production taxes |
1.62 |
1.18 |
0.44 |
37.3% | ||||||||
Depreciation, depletion, amortization and accretion |
13.77 |
23.11 |
(9.34) |
-40.4% | ||||||||
General and administrative expenses |
3.89 |
4.29 |
(0.40) |
-9.3% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.65 |
$ |
1.88 |
$ |
(0.23) |
-12.2% | |||||
Gathering and transportation costs and production taxes |
0.27 |
0.20 |
0.07 |
35.0% | ||||||||
Depreciation, depletion, amortization and accretion |
2.30 |
3.85 |
(1.55) |
-40.3% | ||||||||
General and administrative expenses |
0.65 |
0.71 |
(0.06) |
-8.5% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly.
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data.
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Balance Sheets | |||||||
(Unaudited) | |||||||
December 31, |
December 31, | ||||||
2016 |
2015 | ||||||
(In thousands, except | |||||||
share data) | |||||||
Assets |
|||||||
Current assets: |
|||||||
Cash and cash equivalents |
$ |
70,236 |
$ |
85,414 | |||
Receivables: |
|||||||
Oil and natural gas sales |
43,073 |
35,005 | |||||
Joint interest |
21,885 |
22,000 | |||||
Insurance |
30,100 |
12 | |||||
Income Taxes |
11,943 |
- | |||||
Total receivables |
107,001 |
57,017 | |||||
Prepaid expenses and other assets |
14,504 |
26,879 | |||||
Total current assets |
191,741 |
169,310 | |||||
Total property and equipment |
7,953,402 |
7,923,296 | |||||
Less accumulated depreciation, depletion and amortization |
7,406,349 |
6,933,247 | |||||
Net property and equipment |
547,053 |
990,049 | |||||
Deferred income taxes |
- |
27,595 | |||||
Restricted deposits for asset retirement obligations |
27,371 |
15,606 | |||||
Income tax receivables |
52,097 |
- | |||||
Other assets |
11,464 |
5,462 | |||||
Total assets |
$ |
829,726 |
$ |
1,208,022 | |||
Liabilities and Shareholders' Deficit |
|||||||
Current liabilities: |
|||||||
Accounts payable |
$ |
81,039 |
$ |
109,797 | |||
Undistributed oil and natural gas proceeds |
26,254 |
21,439 | |||||
Asset retirement obligations |
78,264 |
84,335 | |||||
Long-term debt |
8,272 |
- | |||||
Accrued liabilities |
9,200 |
11,922 | |||||
Total current liabilities |
203,029 |
227,493 | |||||
Long-term debt, less current portion |
1,012,455 |
1,196,855 | |||||
Asset retirement obligations, less current portion |
256,174 |
293,987 | |||||
Other liabilities |
17,105 |
16,178 | |||||
Commitments and contingencies |
- |
- | |||||
Shareholders' deficit: |
|||||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 140,543,545 issued and 137,674,372 outstanding at December 31, 2016; 79,375,662 issued and 76,506,489 outstanding at December 31, 2015 |
1 |
1 | |||||
Additional paid-in capital |
539,973 |
423,499 | |||||
Retained earnings (deficit) |
(1,174,844) |
(925,824) | |||||
Treasury stock, at cost |
(24,167) |
(24,167) | |||||
Total shareholders' deficit |
(659,037) |
(526,491) | |||||
Total liabilities and shareholders' deficit |
$ |
829,726 |
$ |
1,208,022 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Statements of Cash Flows | |||||||
(Unaudited) | |||||||
Twelve Months Ended | |||||||
December 31, | |||||||
2016 |
2015 | ||||||
(In thousands) | |||||||
Operating activities: |
|||||||
Net loss |
$ |
(249,020) |
$ |
(1,044,718) | |||
Adjustments to reconcile net loss to net cash provided by operating activities: |
|||||||
Depreciation, depletion, amortization and accretion |
211,609 |
394,071 | |||||
Ceiling test write-down of oil and natural gas properties |
279,063 |
987,238 | |||||
Gain on exchange of debt |
(123,923) |
- | |||||
Debt issuance costs write-off/amortization of debt items |
2,548 |
4,411 | |||||
Share-based compensation |
11,013 |
10,242 | |||||
Derivative (gain) loss |
2,926 |
(14,375) | |||||
Cash receipts on derivative settlements |
4,746 |
6,703 | |||||
Deferred income taxes |
28,392 |
(203,272) | |||||
Asset retirement obligation settlements |
(72,320) |
(32,555) | |||||
Income taxes |
(64,274) |
(7) | |||||
Changes in operating assets and liabilities |
(16,580) |
25,490 | |||||
Net cash provided by operating activities |
14,180 |
133,228 | |||||
Investing activities: |
|||||||
Investment in oil and natural gas properties and equipment |
(48,606) |
(230,161) | |||||
Changes in operating assets and liabilities associated with investing activities |
(35,194) |
(55,425) | |||||
Proceeds from sales of assets |
1,500 |
372,939 | |||||
Purchases of furniture, fixtures and other |
(96) |
(1,278) | |||||
Net cash provided by (used in) investing activities |
(82,396) |
86,075 | |||||
Financing activities: |
|||||||
Borrowings of long-term debt - revolving bank credit facility |
340,000 |
263,000 | |||||
Repayments of long-term debt - revolving bank credit facility |
(340,000) |
(710,000) | |||||
Issuance of Second Lien Term Loan |
- |
297,000 | |||||
Issuance of 1.5 Lien Term Loan |
75,000 |
- | |||||
Payment of interest on 1.5 Lien Term Loan |
(2,570) |
||||||
Debt exchange/issuance costs |
(18,464) |
(6,669) | |||||
Other |
(928) |
(886) | |||||
Net cash provided by (used in) financing activities |
53,038 |
(157,555) | |||||
Increase (decrease) in cash and cash equivalents |
(15,178) |
61,748 | |||||
Cash and cash equivalents, beginning of period |
85,414 |
23,666 | |||||
Cash and cash equivalents, end of period |
$ |
70,236 |
$ |
85,414 |
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 (Loss) to Net Income (Loss) Excluding Special Items
"Net Income (Loss) Excluding Special Items" does not include the unrealized commodity derivative (gain) loss, certain cost recovery from insurance settlement, default in payment by joint interest partners, write-down of debt issue costs, termination fee related to Yellow Rose sale, a contingent assessment provision, ceiling test write-down of oil and natural gas properties, gain on exchange of debt, other non-operating costs, and associated income tax adjustments. 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, | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
(In thousands, except per share amounts) | |||||||||||||||
(Unaudited) | |||||||||||||||
Net income (loss) |
$ |
16,483 |
$ |
(51,606) |
$ |
(249,020) |
$ |
(1,044,718) | |||||||
Unrealized commodity derivative (gain) loss |
65 |
(658) |
7,672 |
(7,672) | |||||||||||
Certain cost recovery from insurance settlement |
(11,028) |
- |
(11,028) |
- | |||||||||||
Default in payment by joint interest partners |
1,622 |
1,564 |
3,615 |
1,564 | |||||||||||
Write-down debt issue costs |
- |
1,183 |
1,368 |
3,157 | |||||||||||
Termination fee related to Yellow Rose sale |
- |
666 |
- |
666 | |||||||||||
Contingent assessment provision |
- |
- |
- |
1,000 | |||||||||||
Ceiling test write-down of oil and natural gas properties |
- |
32,388 |
279,063 |
987,238 | |||||||||||
Gain on exchange of debt |
37 |
- |
(123,923) |
- | |||||||||||
Other non operating costs |
- |
964 |
- |
2,155 | |||||||||||
Income tax adjustment … |
540 |
(15,021) |
(23,202) |
(161,062) | |||||||||||
Net income (loss) excluding special items |
$ |
7,719 |
$ |
(30,520) |
$ |
(115,455) |
$ |
(217,672) | |||||||
Basic and diluted income (loss) per common share, excluding special items |
$ |
0.06 |
$ |
(0.40) |
$ |
(1.21) |
$ |
(2.87) |
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Reconciliation of Net Income (Loss) to Adjusted EBITDA
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative (gain) loss, default in payment by joint interest partners, write-down of debt issue cost, termination fee related to Yellow Rose sale, gain on exchange of debt, a contingent assessment provision and other non-operating costs. 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 (loss), 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 (loss) to EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Three Months Ended |
Twelve Months Ended | ||||||||||||||
December 31, |
December 31, | ||||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||||
(In thousands) | |||||||||||||||
(Unaudited) | |||||||||||||||
Net income (loss) |
$ |
16,483 |
$ |
(51,606) |
$ |
(249,020) |
$ |
(1,044,718) | |||||||
Income tax expense (benefit) |
1,017 |
(36,756) |
(43,376) |
(202,984) | |||||||||||
Net interest expense |
11,508 |
25,419 |
92,109 |
97,205 | |||||||||||
Depreciation, depletion, amortization and accretion |
38,883 |
67,933 |
211,609 |
394,071 | |||||||||||
Ceiling test write-down of oil and natural gas properties |
- |
32,388 |
279,063 |
987,238 | |||||||||||
EBITDA |
67,891 |
37,378 |
290,385 |
230,812 | |||||||||||
Adjustments: |
|||||||||||||||
Unrealized commodity derivative (gain) loss |
65 |
(658) |
7,672 |
(7,672) | |||||||||||
Default in payment by joint interest partners |
1,622 |
1,564 |
3,615 |
1,564 | |||||||||||
Write-down debt issue costs |
- |
1,183 |
1,368 |
3,157 | |||||||||||
Termination fee related to Yellow Rose sale |
- |
666 |
- |
666 | |||||||||||
Gain on exchange of debt |
37 |
- |
(123,923) |
- | |||||||||||
Contingent assessment provision |
- |
- |
- |
1,000 | |||||||||||
Other non operating costs |
- |
964 |
- |
2,155 | |||||||||||
Adjusted EBITDA |
$ |
69,615 |
$ |
41,097 |
$ |
179,117 |
$ |
231,682 | |||||||
Adjusted EBITDA Margin |
60% |
39% |
45% |
46% |
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Feb. 8, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its fourth quarter 2016 financial and operational results after the market closes on Wednesday, March 1. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Thursday, March 2 at 9:30 a.m. Eastern Time (8:30 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through March 9, 2017 by dialing 1-201-612-7415 and using the passcode 13653711. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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.
Contact |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Feb. 3, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its year-end 2016 proved reserves, production for the fourth quarter and full year of 2016, an update on the flow rate at SS 349 A-18 well at Mahogany and an extension on the appeal before the United States Department of Interior Board of Land Appeals ("IBLA") regarding Bureau of Ocean Energy Management (BOEM) orders.
Year-End 2016 Proved Reserves
The Company's year-end 2016 SEC proved reserves were 74.0 million barrels of oil equivalent ("Boe"), or 444.0 billion cubic feet ("Bcfe"), with 55% comprised of liquids (44% crude oil and 11% natural gas liquids ("NGLs")) and 45% natural gas. Approximately 64% of our 2016 proved reserves were classified as proved developed producing, 23% as proved developed non-producing and 13% as proved undeveloped. Total production of approximately 15.4 million Boe in 2016 was substantially offset by upward revisions due to performance despite lower SEC average prices.
The present value of our reported SEC proved reserves, discounted at 10% ("PV-10"), was $754.9 million. The 2016 SEC PV-10 is based on an average crude oil price of $39.25 per barrel and average natural gas price of $2.48 per Mcf, both before adjustment for quality, transportation fees, energy content, and regional price differentials. For 2015, the average crude oil price was $46.79 per barrel and $2.59 per Mcf and PV-10 was $965 million.
For comparative purposes, utilizing the forward closing prices on the New York Mercantile Exchange (NYMEX) for crude oil and natural gas on December 30, 2016 (the last trading day of 2016), total proved reserves at December 31, 2016 would have been 77.6 million Boe, with a PV-10 value of $1.2 billion, an increase of $457.3 million over the SEC PV-10. This would also have resulted in a reserve replacement rate of 102% in 2016 over 2015. The NYMEX based PV-10 uses an un-weighted average crude oil price of $56.31 per barrel and $3.07 per Mcf for natural gas as shown in the table below.
In the SEC case, positive revisions totaled 14.2 million Boe, primarily as a result of better than projected performance in several of our key fields, the addition of certain incremental proved drilling locations, as well as ongoing success in managing, and reducing lease operating expenses across the vast majority of our asset base, thereby extending field life. Offsetting our positive technical reserves gains, was a 1.2 million Boe negative revision to proved reserves due to a 16% decline in the crude oil price and a 4% decline in the natural gas price (based on SEC rules and protocol), which are used to calculate 2016 proved reserves.
Proved Reserve Reconciliation | ||||||||||
Year To Date 2016 | ||||||||||
Oil & NGLs |
PV-10(1) | |||||||||
(MBbls) |
GAS (MMcf) |
MMcfe |
MBoe |
($ in thousands) | ||||||
Balance, December 31, 2015 |
42,118 |
205,416 |
458,126 |
76,354 |
$ 965,631 | |||||
Revisions due to: |
||||||||||
Pricing (2) |
(852) |
(2,300) |
(7,411) |
(1,235) |
||||||
Performance (3) |
8,512 |
34,414 |
85,485 |
14,247 |
||||||
Production |
(8,743) |
(39,731) |
(92,188) |
(15,365) |
||||||
Balance, December 31, 2016 |
41,036 |
197,798 |
444,011 |
74,002 |
$ 754,933 |
(1) |
PV-10 for this presentation excludes any provision for asset retirement obligations or income taxes. |
(2) |
In accordance with guidelines established by the SEC, our estimated proved reserves as of December 31, 2016 were determined to be economically producible under existing economic conditions, which requires the use of the 12-month average commodity price for each product, calculated as the unweighted arithmetic average of the first-day-of-the-month price for the year end December 31, 2016. The West Texas Intermediate posted price and the Henry Hub spot price were utilized as the referenced price and after adjusting for quality, transportation, fees, energy content and regional price differentials. In determining the estimated realized price for NGLs, a ratio was computed for each field of the NGLs realized price compared to the crude oil realized price. Then, this ratio was applied to the crude oil price using SEC guidance. Such prices were held constant throughout the estimated lives of the reserves. Future production and development costs are based on year-end costs with no escalations. |
(3) |
Due to positive performance revisions and lease operating expense reductions. |
The table below is a reconciliation of proved reserves calculated at SEC pricing compared to proved reserves at NYMEX on December 30, 2016.
YE 2016 - SEC Pricing (1) |
YE 2016 - NYMEX Strip Pricing (2) |
NYMEX vs. SEC Variance | ||||||||||||||||
Equiv |
Equiv |
Equiv |
Equiv |
Equiv |
Equiv |
|||||||||||||
MMcfe |
MBoe |
PV-10 |
MMcfe |
MBoe |
PV-10 |
MMcfe |
MBoe |
PV-10 | ||||||||||
PDP |
283,881 |
47,314 |
$449,407 |
301,198 |
50,200 |
$ 735,549 |
17,317 |
2,886 |
$286,142 | |||||||||
PDNP |
104,362 |
17,394 |
228,918 |
109,823 |
18,304 |
338,696 |
5,461 |
910 |
109,778 | |||||||||
PUD |
55,769 |
9,295 |
76,608 |
54,577 |
9,096 |
138,016 |
(1,192) |
(199) |
61,408 | |||||||||
Total Proved |
444,011 |
74,002 |
$754,933 |
465,598 |
77,600 |
$1,212,261 |
21,587 |
3,598 |
$457,328 | |||||||||
PROB |
234,212 |
39,035 |
238,235 |
39,706 |
4,022 |
670 |
||||||||||||
Total 2P |
678,224 |
113,037 |
703,833 |
117,306 |
25,609 |
4,268 |
(1) SEC pricing is based on $39.25 oil and $2.48 gas for all years. | |||||||||||
(2) NYMEX strip price is based on the following forward strip. | |||||||||||
Year |
Oil |
Gas | |||||||
2017 |
$ 55.99 |
$ 3.62 | |||||||
2018 |
56.59 |
3.14 | |||||||
2019 |
56.10 |
2.87 | |||||||
2020 |
56.05 |
2.88 | |||||||
2021 |
56.21 |
2.90 | |||||||
2022 |
56.51 |
2.93 | |||||||
2023+ |
56.77 |
3.12 |
• |
Boe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). NGLs are converted to barrels using a ratio of 42 gallons to one barrel. The energy-equivalent ratios do not assume price equivalency, and the energy-equivalent prices for crude oil, NGLs, and natural gas may differ significantly. |
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "As a result of the prolific projects that we acquired and developed over the last few years and the exceptional reservoirs characteristics of the Gulf of Mexico, we almost replaced our entire 2016 production through performance revisions alone despite a 16.1% drop in crude oil prices and a 4.2% decrease in natural gas prices. Several of our most important fields performed substantially better than previously predicted by our independent third party reservoir engineering auditors, primarily due to probable and possible reserve recovery and we believe that a number of our fields have further unrecognized upside."
"Despite our dramatically reduced capital budget in 2016 that included the completion of only one new well, we successfully held our SEC reserves steady from the prior year. This was also accomplished despite the negative impact of lower prices used in SEC reserve calculations. When we evaluate our reserves based on the forward NYMEX strip price, not only do we see reserve growth, but the value of our proved reserves increases by $457.3 million," concluded Mr. Krohn.
Fourth Quarter and Full Year 2016 Production
Production for the fourth quarter of 2016 was 3.7 million Boe (or 22.2 Bcfe), compared to the fourth quarter 2015 of 4.1 million Boe (or 24.7 Bcfe). Fourth quarter 2016 production was comprised of 1.7 million barrels of oil, 0.4 million barrels of natural gas liquids (NGLs) and 10.0 Bcf of natural gas, at an average realized sales price of $30.83 per Boe or $5.14 per Mcfe. Oil and NGLs production were 55% of total production in the fourth quarter of 2016 compared to 57% of total production in the fourth quarter of 2015.
For the full year 2016, production was 15.4 MMBoe (or 92.2 Bcfe), compared to 17.0 MMBoe (or 102.3 Bcfe) in 2015. Total 2016 production was comprised of 7.2 million barrels of oil, 1.5 million barrels of NGLs and 39.7 Bcf, at an average realized sales price of $25.76 per Boe.
SS 349 A-18 Flow Rate Update at Mahogany
The recently completed Ship Shoal 349 (Mahogany) A-18 well recently reached a production rate of 5,217 Boe per day (4,032 barrels of oil per day and 7.1 MMcf per day).
BOEM Update
In 2016, the Company received orders from the BOEM directing the Company to provide financial assurances in the form of additional security with respect to certain designated leases, rights of way and rights of use and easement. Previously, we have filed appeals with the United States Department of Interior Board of Land Appeals ("IBLA") regarding these BOEM orders. The IBLA, acknowledging that the BOEM and the Company were seeking to resolve the BOEM orders through settlement discussions, agreed to stay the effectiveness of the orders to May 31, 2017.
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 approximately 52 fields in federal and state waters (50 producing and two fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 490,000 gross acres on the Gulf of Mexico Shelf and approximately 260,000 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, 2015 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
SOURCE W&T Offshore, Inc.
HOUSTON, Jan. 26, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that the Ship Shoal 349 A-18 well, its most recently completed well in its Mahogany field, was successfully brought on production on January 17, 2017. The well is ramping up to full rates and thus far has achieved a production rate of 3,275 barrels of oil per day and 5.6 million cubic feet of natural gas per day, for a total of approximately 4,200 barrels of oil equivalent (Boe) per day at a flowing tubing pressure of over 9,000 psi. The Company expects to increase the A-18 production rate to in excess of 5,000 Boe per day consistent with its reservoir management plan.
As previously reported, the SS 349 A-18 well logged 149 feet of net oil pay in five zones and extended the size and depth of the Mahogany field. The well was completed in the main objective 'T' Sand, with future recompletion opportunities to additional pay zones available in the well. This deep shelf subsalt well was drilled to a total vertical depth of approximately 20,000 feet in a water depth of 372 feet on the western side of the Mahogany field. W&T holds a 100% working interest in the Mahogany field.
Tracy Krohn, W&T Offshore's Chairman and CEO, stated, "The SS 349 A-18 well is proving to be another substantial producer from an outstanding field that continues to expand in size. With its high quality rock properties, including very high porosity and permeability, we anticipate strong production rates from this well for years into the future. Our SS 349 A-14 well that originally discovered the 'T' sand in July 2013 has produced a total of 3.8 MMBoe gross from the 'T' sand to date. As a result, the economic returns on these wells are excellent.
"As we stated on January 24th, our 2017 capital budget includes the drilling and completion of three additional wells in the Mahogany field, with each project expected to achieve a rate of return in excess of 100%, with a relatively quick payback. We have multiple 'P' Sand, 'T' Sand and 'Q' Sand targets and the thick stacked pay sands that will offer drilling and recompletion opportunities for years to come," concluded Mr. Krohn.
Tom Murphy, W&T Offshore's COO, stated, "The A-18 well has exceeded our pre-drill production rate expectations. Initial indications are that the A-18 well is located in the same large reservoir as the original 'T' sand discovery well, the A-14. This provides excellent encouragement for our expansion plans in this reservoir including exploitation of the newly discovered 'U' sand," concluded Mr. Murphy.
The Company also announced that it has posted a new investor presentation to its website that includes slides concerning projects planned for the 2017 capital program. The presentation slides can be accesses from the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations."
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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, 2015 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Jan. 24, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI), today announced that its Board of Directors has approved a 2017 capital expenditure budget of $125 million, excluding potential acquisitions. The Company has also provided production and expense guidance for 2017 and expects total production in 2017 to be approximately 4% higher than the mid-point of the Company's expected production in 2016.
2017 Capital Program
W&T currently anticipates drilling six to eight wells during 2017 in the Gulf of Mexico in a program that is expected to be generally balanced between exploration and development projects and between wells located on the Shelf and in the Deepwater. The 2017 projects meet the Company's budget criteria of having a very high probability of success, expected high rates of return and short-term payout, and the ability to boost production levels in 2017 or early 2018.
The 2017 capital plan includes completing the Ship Shoal 349 "Mahogany" A-18 well, which was drilled to total depth in late 2016 and put on production in mid-January, and the drilling and completion of three additional wells in the Mahogany field. Each of these projects is expected to achieve a rate of return in excess of 100%, with a relatively quick payback. The plan also includes the drilling and completion of two wells at the Ewing Bank 910 field, which are expected to average a rate of return in excess of 100%, with an average projected payout in approximately one year.
Additionally, the 2017 plan includes performing between 20 and 25 recompletions at a cost of approximately $26 million. These recompletions on average are projected to have very good rates of return and short payback cycles. Approximately two-thirds of the entire capital budget is directed at projects that will come on line and start producing in 2017.
Tracy Krohn, W&T Offshore's Chairman and CEO, stated, "By virtue of our long history of finding and creating successful drilling opportunities in the Gulf of Mexico's prolific stacked reservoirs, we have developed a substantial inventory of low-risk, high-return projects in producing fields.
"Due to the recent improvement in commodity prices, combined with our continued success at reducing costs and optimizing our operations, we expect to realize higher adjusted EBITDA and better adjusted EBITDA margins in 2017 than what we experienced in 2015 and 2016. As a result, we are substantially increasing our capital spending in 2017 over 2016 levels; at the same time we expect to build cash on hand while maintaining the flexibility to adjust our spending plans as market conditions change. We intend to drill within our net cash flow generating capabilities, as well as maintain and build liquidity.
"Our 2017 capital program is focused on projects with an excellent probability of success and rates of return of between 80% to well over 100%. The projects are also located near existing infrastructure and can be brought on production quickly, offering immediate cash generation.
"Our Mahogany field is expected to be an important part of our capital program in 2017, with a substantial inventory of projects to choose from, including low-risk development drilling, exploration that could continue to extend the field's size, and quick payout projects such as recompletions and sidetrack drilling. We have multiple 'P' Sand, 'T' Sand and 'U' Sand targets in our Mahogany field, which will provide drilling opportunities into 2018 and beyond. The thick stacked pay sands that we are de-risking in the field also offer extensive recompletion opportunities as we exploit the proven non-producing zones in the field. To more precisely target the formations, we will be utilizing our recent analysis of our new WAZ seismic data over the field that has produced a much clearer image of the sub-salt formations. The vast majority of the value in the 2017 plan should be generated at Mahogany, so we feel confident that our capital will achieve above-average rates of return.
"The Gulf of Mexico can be a highly profitable basin for operators that know how to exploit its exceptional rock properties and manage offshore operating costs. We are optimistic that we can take advantage of the numerous opportunities we have identified, as well as future opportunities, and we can generate strong margins from the basin," he concluded.
2017 Production and Expense Guidance
Our guidance for the first quarter 2017 and full year 2016 and 2017 is provided in the table below and 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.
First Quarter |
Full Year | |||||
Production |
2017 |
2017 |
2016 | |||
Oil and NGLs (MMBbls) |
2.0 - 2.3 |
8.3 - 9.2 |
8.3 - 9.2 | |||
Natural gas (Bcf) |
10.2 - 11.3 |
41.4 - 45.7 |
37.7 - 41.6 | |||
Total (Bcf) |
22.5 - 24.9 |
91.1 - 100.6 |
87.6 - 96.8 | |||
Total (MMBoe) |
3.7 - 4.1 |
15.2 - 16.8 |
14.6 - 16.1 | |||
Operating Expenses |
First Quarter |
Full Year | ||||
($ in million) |
2017 |
2017 |
2016 | |||
Lease operating expenses |
$46 - $51 |
$167 - $185 |
$153 - $169 | |||
Gathering, transportation & |
$5.6 - $6.2 |
$23 - $26 |
$23 - $26 | |||
General and administrative |
$14 - $15 |
$53 - $59 |
$58 - $64 | |||
Income tax rate benefit |
nm |
14.9% |
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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, 2015 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Jan. 5, 2017 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that its Ship Shoal 359 A-18 well has logged 149 feet of net oil pay in five zones and extended the size and depth of the Mahogany field. The SS 349 A-18 well was drilled on the western side of the Mahogany field to extend the productive limit of the 'T' sand, which was discovered in mid-2013 by the A-14 well. The A-18 well not only confirmed that the 'T' sand is present and oil bearing on the west side of the field but it also logged and penetrated four additional attractive pay sands in addition to the main 'T' sand target. After casing the 'T' sand, the Company drilled an exploratory tail (approximately 950 feet deeper) beneath the main well target to test seismic reflectors imaged with its newest 3D seismic data and discovered an additional pay interval in a deeper 'U' sand interval. The success of the A-18 well is expected to generate additional drilling locations for the company. W&T holds a 100% working interest in the Mahogany field.
Tracy Krohn, W&T Offshore's Chairman and CEO, stated, "After pausing our Mahogany field development drilling program since early 2015 when commodity prices slipped, we are very pleased to have resumed drilling activity there to further unlock the significant potential of this huge field. We are benefitting from our recent analysis of our new WAZ seismic data over the field, which allows us to more clearly image the sub-salt formations and assess the additional upside of this field.
"With a number of development and low-risk exploration locations yet to be drilled, the Mahogany field is expected to be the cornerstone of our capital program in 2017 and possibly beyond. Our focus on lowering drilling and operating costs in the Gulf of Mexico, combined with Mahogany's outstanding reservoir characteristics and existing infrastructure on the Shelf, delivers very compelling economic returns for our shareholders.
"The A-18 well allowed the Company to acquire its first core data from this important reservoir with rock permeability estimated to exceed one darcy, confirming the excellent flow potential of this exceptional reservoir. By comparison, the permeability of shale plays in the Permian Basin is often stated as having permeabilities in nanodarcies. A nanodarcy is one billionth of a darcy, which is obviously significantly less than a darcy," concluded Mr. Krohn.
Tom Murphy, W&T Offshore's COO, stated, "The A-18 success exceeded our pre-drill expectations and underscores the large potential in the prolific Mahogany 'T' sand. It achieved our main well objectives in the primary target zone and logged 149 feet of pay in a total of five reservoirs. By design, the well penetrated the field's historic producing intervals - the 'P' and 'Q' sands - in the highest structural position in the field's history. This sets up a very attractive attic recovery project in an area of the field with good water drive characteristics and recovery efficiency.
"Our exploratory tail has confirmed the presence of hydrocarbon-bearing sands in a trapped position beneath our currently productive 'T' sand and further extends the vertical column in the field to these previously unpenetrated reservoirs. The well's success is expected to generate several high-quality additions to our organic drilling inventory, including a future extension of the main 'T' sand based on this most recent penetration, a crestal development well opportunity to exploit the western 'P' and 'Q' attic area, and deeper drilling opportunities to exploit and target the newly discovered deep 'U' sand.
"Now that we have confirmed that the 'U' sand is oil bearing below our deepest current producing sand depth, the Company will evaluate opportunities to exploit this newly discovered resource potential across the field and will also look to continue extending the field's vertical oil column," Mr. Murphy concluded.
The SS 349 A-18 well was drilled to a total vertical depth of approximately 20,000 feet in a water depth of 372 feet. It will initially be completed in the main objective Upper 'T' Sand and is expected to be placed on production early in the first quarter of 2017. The well completion will be set up for a low-cost future recompletion to the untested deeper 'U' sand, and the three additional sands in the 'P' and 'Q' intervals will be exploited as future recompletions or will be considered for further development well locations to accelerate value.
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Nov. 2, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its third quarter 2016 operational and financial results, as well as its 2016 fourth quarter and full year production and expense guidance. Some of the key items for the third quarter include:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "We are pleased to have received the support of our shareholders and senior noteholders in completing our Exchange Transaction, significantly improving our liquidity which in turn will allow us to turn our focus toward new capital projects. While operating margins are still below our historic levels, they have improved from early in the year, allowing us to expand our capital program in 2016, currently estimated at $60 million, and pursue projects that were delayed when margins began declining rapidly. We are currently working on our plan for 2017 and expect to increase our capital budget to levels well above 2016 expenditures. We intend to devote more capital to drilling and completing new wells along with an expanded recompletion program.
"We are currently drilling the Ship Shoal 349 A-18 development well in our Mahogany field, targeting the 'T' sand that has produced so prolifically in the field's A-14 well since mid-2013. During the industry downturn, we remained focused on evaluating the drilling and production data from certain of the other wells drilled in the field, as well as the advanced seismic data we have acquired and interpreted to help us better understand Mahogany's sub-salt opportunities. Additionally, we have a number of recompletion and workover opportunities planned, including two workovers at Mahogany, which offer low risk and solid returns from wells that were drilled in stacked reservoirs with multiple pay zones. These projects help us to maintain our production profile with a modest capital budget.
"Although we are encouraged by the improved commodity prices, we remain diligent about cost control and are maintaining a prudent approach to spending. Over the last two years, we have reduced LOE by 48% and G&A expense by 40% and believe that we can continue to drive down costs. Our objective is to maintain steady production on a modest capital budget in the range of $75 million to $150 million per year until we are confident that the time is right to return to a more robust growth profile," added Mr. Krohn.
Exchange Transaction: On September 7, 2016, we consummated an exchange transaction that reduced our long-term debt by $408.2 million, excluding our new 1.5 Lien Term Loan (defined below) and before changes that result from accounting for the Exchange Transaction as a Troubled Debt Restructuring (described below). We exchanged approximately 79% of our 8.500% Senior Notes, due June 15, 2019 (the "Unsecured Senior Notes") in an aggregate principal amount of $710.2 million for: (i) 9.00%/10.75% Senior Second Lien PIK Toggle Notes, due May 2020, in an aggregate principal amount of $159.8 million (the "Second Lien PIK Toggle Notes"); (ii) 8.50%/10.00% Third Lien PIK Toggle Notes, due June 2021, in an aggregate principal amount of $142.0 million (the "Third Lien PIK Toggle Notes"); and (iii) 60.4 million shares of our common stock (the "Debt Exchange"). The Second Lien PIK Toggle Notes and Third Lien PIK Toggle Notes contain payment-in-kind ("PIK") interest provisions, where certain semiannual interest is added to the principal amount instead of being paid in cash in the then current semiannual period. In conjunction with the Debt Exchange, we issued a $75 million 1.5 Lien Term Loan with an interest rate of 11%, due November 2019 (the "1.5 Lien Term Loan") (collectively with the Debt Exchange, the "Exchange Transaction"). We accounted for the Exchange Transaction as a Troubled Debt Restructuring ("TDR") pursuant to the guidance under Accounting Standard Codification 470-60, Troubled Debt Restructuring. The Exchange Transaction resulted in a gain of $124.0 million due to the fact that the sum of the future undiscounted principal and interest payments of the newly issued debt was less than the net carrying value of the original debt (after adjusting for the consideration in the form of the shares of common stock, transaction costs of the Exchange Transaction, and the funds received from the issuance of the 1.5 Lien Term Loan). Under TDR accounting, all future principal and interest payments have been recorded as a liability; therefore, no interest expense was recorded for the new debt in September 2016 and no future interest expense will be recorded for the new debt, thus our reported interest expense will be significantly less than the contractual interest payments through the terms of the new debt. To the extent interest on the new debt is paid in cash in future periods it will reduce the liability recorded in connection with such debt.
Production, Revenues and Price: For the third quarter of 2016, our oil production was 1.8 million barrels, down 9.2% from the third quarter of 2015. NGL production was 371,571 barrels, down 4.4% from the third quarter of 2015 and natural gas production was 9.9 billion cubic feet ("Bcf") for the third quarter of 2016, down 14.6% from the third quarter of 2015. Our combined total production was 3.8 million barrels of oil equivalent ("MMBoe") in the third quarter of 2016, down 11.2% from the third quarter of 2015. Production was lower in the third quarter of 2016 compared to the third quarter of 2015 due to natural production declines, pipeline outages, field and platform maintenance and the loss of production as a result of the sale of our Yellow Rose field in October 2015. This was partially offset by new oil production from the development of certain deepwater fields within the last year (Big Bend, Dantzler and EW 910).
During the quarter we experienced production deferrals attributable to third-party pipeline outages, operational issues, and maintenance, which occurred at Mahogany, East Cameron 321 A and various other locations. We estimate production deferrals reduced our quarterly production by approximately 0.2 MMBoe during the third quarter of 2016.
Revenues for the third quarter of 2016 were $107.4 million compared to $126.2 million in the third quarter of 2015. The decrease in revenues was primarily due to a 3.3% decline in realized commodity prices, combined with an 11.2% decrease in production. Our average realized crude oil sales price was down $4.23 per barrel, or 9.6%, between the two quarters. NGLs prices improved 7.6%, or $1.28 per barrel and natural gas prices improved 8.9% or $0.24 per Mcf from the third quarter of 2015. During the third quarter of 2016, our average realized sales price for oil was $39.62 per barrel, $18.02 per barrel for NGLs and $2.93 per Mcf for natural gas. On a combined basis, we sold 41,508 Boe per day at an average realized sales price of $27.97 per Boe compared to 46,757 Boe per day sold at an average realized sales price of $28.92 per Boe in the third quarter of 2015.
West Texas Intermediate ("WTI") crude oil prices averaged $41.35 per barrel for the first nine months of 2016 compared to our average realized crude oil price of $35.01 per barrel. WTI is frequently used to value domestically produced crude oil, and the majority of our oil production is priced using the spot price for WTI as a base price, then adjusted for the type and quality of crude oil and other factors. Just like crude oil prices, the differentials for our offshore crude oil have also experienced significant volatility. For example, the monthly average differentials of WTI crude oil prices versus Light Louisiana Sweet ("LLS"), Heavy Louisiana Sweet ("HLS") and Poseidon crude oil prices for the first nine months of 2016 were a positive $1.79 and $0.87, and a negative $3.58 per barrel, respectively. The majority of our crude oil is priced similar to Poseidon and, therefore, is experiencing negative differentials. In addition, a few of our crude oil fields have a negative quality bank adjustment due to crude oil quality which reduces our crude oil price realizations.
Lease Operating Expenses: LOE, which includes base lease operating expenses, insurance premiums, workovers, and facilities maintenance, decreased $7.5 million, or 16.7%, to $37.5 million in the third quarter of 2016 compared to the third quarter of 2015. On a per Boe basis, LOE decreased to $9.82 per Boe in the third quarter of 2016, a 6.2% reduction compared to $10.47 per Boe in the third quarter of 2015. On a component basis, base lease operating expenses decreased $1.1 million, workover expense decreased $4.9 million, insurance premiums decreased $1.7 million and facilities maintenance increased $0.2 million. Base lease operating expenses decreased primarily due to lower costs from service providers and the elimination of field expenses related to the Yellow Rose field which was sold in October 2015, partially offset by costs related to our new deepwater fields at Dantzler and Big Bend and lower production handling fees (cost offsets) at our Mississippi Canyon 243 field (Matterhorn). The decrease in workover costs was primarily due to the sale of the Yellow Rose field and reduced activities offshore.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for ARO, decreased to $13.49 per Boe for the third quarter of 2016 from $22.62 per Boe for the third quarter of 2015. On a nominal basis, DD&A decreased to $51.5 million for the third quarter of 2016 from $97.3 million for the third quarter of 2015 due to a decrease in the DD&A rate per Boe and lower production volumes. DD&A on a per Boe and nominal basis decreased primarily due to the ceiling test write-downs recorded during 2015 and the first half of 2016 (the third quarter 2016 ceiling test write-down will not affect the DD&A rate until the fourth quarter of 2016) and lower capital expenditures in relation to DD&A expense, which lowers the full-cost pool subject to DD&A. In addition, the proceeds from the sale of our Yellow Rose field reduced the full cost pool along with the removal of future development costs associated with the Yellow Rose field reserves. Other factors affecting the DD&A rate are lower future development costs and lower proved reserves.
Ceiling test write-down of oil and natural gas properties: For the third quarter of 2016, we recorded a non-cash ceiling test write-down of $57.9 million as the book value of our proved oil and natural gas properties exceeded the ceiling test limitation. The write-down is primarily the result of decreases in prices for crude oil as the twelve month moving average has continued to move down under SEC pricing methodology. For the third quarter of 2015, the ceiling test write-down was $441.7 million.
General and Administrative Expenses ("G&A"): G&A decreased $3.8 million, or 23.2% to $12.7 million for the third quarter of 2016 compared to the third quarter of 2015. The decrease was primarily due to reclassifying transaction costs associated with the Exchange Transaction previously recorded in G&A expense to Gain on exchange of debt. In addition, decreases in headcount related expense (salaries, benefits, and contractor expenses) and elimination of certain employee benefits also contributed to the decrease.
Derivatives: For the third quarter of 2016, we recorded a $0.4 million net derivative loss on derivative contracts for crude oil and natural gas. For the third quarter of 2015, there was a $10.2 million net derivative gain recorded. A report providing our commodity derivative positions is posted to our website.
Interest expense: Interest expense incurred was $23.7 million in the third quarter of 2016, compared to $28.8 million in the third quarter of 2015. The decrease was primarily attributable to the Exchange Transaction. Interest expense was reduced for the Unsecured Senior Notes exchanged on September 7, 2016 (the close date). For the new debt issued, undiscounted future cash flows (principal, PIK and cash interest) are recorded as liabilities under the accounting guidance for TDR; therefore, no interest expense was recorded for the new debt for the period of September 7, 2016 to September 30, 2016. In addition, interest expense was lower due to lower average borrowings on the revolving bank credit facility. To the extent interest on the new debt is paid in cash in future periods it will reduce the liability recorded in connection with such debt.
Gain on Exchange of Debt: Under the accounting guidance for TDR, a gain of $124.0 million was recorded related to the Exchange Transaction. The gain was measured as the difference between (i) the sum of; the future undiscounted principal and interest payments of the new debt (the Second Lien PIK Toggle Notes, the Third Lien PIK Toggle Notes, and the 1.5 Lien Term Loan); the fair value of the common stock issued; and transaction costs associated with the Exchange Offer of $18.9 million and (ii) the sum of the principal amount of the Unsecured Senior Notes exchanged of $710.2 million, adjusted for related debt premium and debt issuance costs, and the funds received from the issuance of the 1.5 Lien Term Loan.
Income Tax Benefit: Our income tax benefit for the third quarter of 2016 and 2015 was $3.8 million and $18.5 million, respectively. Our annualized effective tax rate for the third quarter of 2016 was not meaningful primarily due to adjustments related to the book gain associated with the Exchange Transaction. For the third quarter 2015, our effective tax rate was 3.7%, and differs from the federal statutory rate of 35% primarily due to the valuation allowance recorded for our deferred tax assets. During the three months ended September 30, 2016 and 2015, we recorded a valuation allowance decrease of $19.1 million and an increase of $156.2 million, respectively, related to federal and state deferred tax assets. Deferred tax assets are recorded related to net operating losses and temporary differences between the book and tax basis of assets and liabilities expected to generate tax deductions in future periods. The realization of these assets depends on recognition of sufficient future taxable income in specific tax jurisdictions in which those temporary differences or net operating losses are deductible. In assessing the need for a valuation allowance on our deferred tax assets, we consider whether it is more likely than not that some portion or all of them will not be realized.
During the third quarter of 2016, we received an income tax refund of $5.6 million that relates to a net operating loss ("NOL") claim for 2015 carried back to 2005. In the second quarter of 2016 we recorded $52.1 million as non-current income tax receivables related to our NOL claims for the years 2012, 2013 and 2014 that were carried back to the years 2003, 2004, 2007, 2010 and 2011. These carryback claims are made pursuant to Internal Revenue Code ("IRC") Section 172(f) which permits certain platform dismantlement, well abandonment and site clearance costs to be carried back 10 years.
In connection with the privately negotiated exchange agreement to exchange a portion of our Unsecured Senior Notes for new Notes due in 2020 and 2021 and for our common stock, we realized a tax gain due to the concession extended by our note holders. This tax gain will be offset by a reduction in our net operating losses and other deferred tax asset attributes. The reduction in our deferred tax assets will be fully offset by a corresponding reduction in our valuation allowance.
Net Income (Loss) & Earnings (Loss) Per Share: We reported net income for the third quarter of 2016 of $45.9 million or $0.48 per common share, compared to a reported net loss of ($477.6) million, or ($6.29) per common share, during the same period in 2015. Excluding special items (including the ceiling test write-down of oil and natural gas properties, gain on exchange of debt, write-off of debt issuance and other non-operating costs, and an unrealized commodity derivative gain or loss, net of an applicable federal income tax adjustment), our net loss for the third quarter of 2016 was ($22.6) million and our loss per common share was ($0.24), compared to the third quarter of 2015 net loss of ($60.0) million, or ($0.79) per common share. Operating results for the third quarter of 2016, excluding special items, were down primarily due to a $18.8 million decrease in revenues resulting from a 3.3% decline in our realized sales prices and an 11.2% decline in production, partially offset by a $7.5 million decrease in LOE, a $3.8 million decrease in G&A and a $45.8 million decrease in DD&A. See the "Reconciliation of Net Loss to Net Loss 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: Adjusted EBITDA and Adjusted EBITDA margin are non-GAAP measures and are defined in the "Non-GAAP Financial Measures" section at the end of this news release.
Net cash used in operating activities for the first nine months of 2016 was $9.2 million compared to net cash provided by operating activities of $134.8 million for the same period in 2015.
Cash flows from operating activities, before changes in working capital and asset retirement obligations ("ARO") settlements, were $42.8 million in the first nine months of 2016, compared to $125.5 million generated over the same period in 2015. Cash flows declined as revenues were $118.4 million lower in the 2016 period compared to the 2015 period while operating expenses were $34.2 million lower over the same time period. Asset retirement obligation settlements totaled $56.2 million in the first nine months of 2016.
Adjusted EBITDA for the third quarter of 2016 was $52.5 million, down from $61.4 million generated over the same period in 2015. Our Adjusted EBITDA margin was 49% for both periods. For the nine months ended September 30, 2016 our Adjusted EBITDA was $109.8 million and our Adjusted EBITDA margin was 39% compared to Adjusted EBITDA of $189.4 million and an Adjusted EBITDA margin of 47% for the same period in 2015.
Liquidity:
On September 7, 2016, we closed on our new $75 million 1.5 Lien Term Loan, the proceeds of which were used to pay transaction costs associated with the Exchange Offer and to repay a portion of the borrowings outstanding under our revolving bank credit facility.
At September 30, 2016, our total liquidity was $222.5 million consisting of cash balances of $73.4 million and $149.1 million of availability under our revolving bank credit facility.
2016 Capital Expenditures Update: Our capital expenditures on an accrual basis for the first nine months of 2016 were $24.1 million ($61.5 million on a cash basis) compared to $192.8 million ($258.3 million on a cash basis) for the first nine months of 2015. Thus far in 2016 our capital expenditures have been directed at completion activities of the Ewing Bank 954 A-8 well, drilling of the A-18 well at Mahogany, recompletions at Virgo (VK 823) and Main Pass 69 and a new pipeline at East Cameron 321. The remainder of the expenditures was associated with other development activities and seismic.
Our capital expenditures for 2016 are currently estimated at $60 million and well below prior year levels. Our plug and abandonment activities for 2016 are currently estimated to total $74 million ($90.2 million over the next twelve months) and are expected to be funded with cash on hand and cash flow from operating activities.
OPERATIONS UPDATE
Ship Shoal 349 A-18 "Mahogany" (100% WI, operated, shelf)
We re-initiated drilling operations on the SS349 A-18, which is expected to reach total target depth of 18,722 feet in the November/December timeframe. We plan on completing and bringing the well on line around the end of the year or possibly early January 2017. The A-18 is a development well. To date, we have penetrated and logged pay in two field sands, the results from which are encouraging. Following the completion of the A-18 well, we expect to conduct workover activities on several wells to further enhance field production, likely beginning in early 2017.
Well Recompletions and Workovers
We have recently finished a recompletion of the A-1 well at Viosca Knoll 823 "Virgo" and the Ewing Bank 954 A-8 well. Both of these wells are performing better than expected (4,400 Boe per day gross, 3,200 Boe per day net, production rate on early tests) and should contribute nicely to fourth quarter production levels.
Bureau of Ocean Energy Management ("BOEM") Matters: The BOEM requires that lessees demonstrate financial strength and reliability according to its regulations or post surety bonds or other acceptable financial assurances, which, among other things, will insure that such decommissioning obligations will be satisfied. Prior to 2015, we were partially exempt from providing such financial assurances. The significant and sustained decline in crude oil and natural gas prices, however, has resulted in the Company in 2015 no longer meeting the relevant financial strength and reliability criteria for such exemptions set forth in the then current regulations and procedures of the BOEM. As a result, we were notified by the BOEM in 2015 that the Company was no longer eligible for any exemption from providing financial assurances to the BOEM.
In February and March 2016, we received several orders from the BOEM ordering the Company to secure financial assurances in the form of additional security in the aggregate of $260.8 million, with amounts specified with respect to certain designated leases, rights of use and easement and rights of way. We filed appeals with the Interior Board of Land Appeals ("IBLA") regarding four of the BOEM orders - specifically the February order requiring the Company to post a total of $159.8 million in additional security and three March orders requiring $101.0 million in additional security. The IBLA, acknowledging that the BOEM and the Company were seeking to resolve the BOEM orders through settlement discussions, has agreed to stay the effectiveness of the orders. This is the third stay that we have received from the IBLA and this latest order extends the effectiveness to January 31, 2017. We submitted a proposal for a tailored plan of compliance in May of 2016 in an effort to seek an acceptable resolution of the orders.
In July 2016, effective September 12, 2016, the BOEM issued NTL #2016-N01, related to obligations for decommissioning activities on the federal OCS, thereby superseding and replacing the prior applicable NTL which was NTL #2008-N07. Implementation of this new NTL could result in us having to obtain additional bonds or other financial assurances and having to post collateral to obtain such additional bonds or other financial assurances. In September of 2016, we submitted to the BOEM a revision of our proposed tailored plan of compliance that we believe to be consistent with a tailored arrangement allowed under NTL #2016-N01. Discussions with the BOEM are ongoing and we are hopeful that we can reach agreement with them on an acceptable tailored plan.
Fourth Quarter and Full Year 2016 Outlook
Our guidance for the fourth quarter and full year 2016 is provided in the table below and represents the Company's best estimate of the range of likely future results. Guidance could be affected by the factors described below in "Forward-Looking Statements."
Fourth Quarter |
Prior Full Year |
Revised Full Year | ||||
Production |
2016 |
2016 |
2016 | |||
Oil and NGLs (MMBbls) |
1.9 - 2.1 |
8.5 - 9.3 |
8.3 - 9.2 | |||
Natural gas (Bcf) |
9.5 - 10.5 |
37.9 - 41.9 |
37.7 - 41.6 | |||
Total (Bcf) |
21.1 - 23.3 |
88.8 - 98.2 |
87.6 - 96.8 | |||
Total (MMBoe) |
3.5 - 3.9 |
14.6 - 16.4 |
14.6 - 16.1 | |||
Operating Exenses |
Fourth Quarter |
Prior Full Year |
Revised Full Year | |||
($ in million) |
2016 |
2016 |
2016 | |||
Lease operating expenses |
$40 - 45 |
$166 - $184 |
$153 - $169 | |||
Gathering, transportation & production taxes |
$6 - $7 |
$22 - $24 |
$23 - $26 | |||
General and administrative |
$15 - $17 |
$61 - $68 |
$58 - $64 | |||
Income tax rate benefit |
n/m |
5.4% |
14.9% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, November 3, 2016, at 8:30 a.m. Eastern 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 approximately two hours after the end of the call until November 10, 2016 and may be accessed by calling 201-612-7415 and using the passcode 13648354#.
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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, 2015 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 | ||||||||||||||
Condensed Consolidated Statements of Income (Loss) | ||||||||||||||
(Unaudited) | ||||||||||||||
Three Months Ended |
Nine Months Ended | |||||||||||||
September 30, |
September 30, | |||||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||||
(In thousands, except per share data) | ||||||||||||||
Revenues |
$ |
107,403 |
$ |
126,228 |
$ |
284,773 |
$ |
403,201 | ||||||
Operating costs and expenses: |
||||||||||||||
Lease operating expenses |
37,520 |
45,039 |
118,611 |
143,500 | ||||||||||
Gathering, transportation costs and production taxes |
5,643 |
4,461 |
18,029 |
15,715 | ||||||||||
Depreciation, depletion, amortization and accretion |
51,500 |
97,329 |
172,726 |
326,138 | ||||||||||
Ceiling test write-down of oil and natural gas properties |
57,912 |
441,688 |
279,063 |
954,850 | ||||||||||
General and administrative expenses |
12,692 |
16,515 |
45,370 |
57,038 | ||||||||||
Derivative (gain) loss |
412 |
(10,231) |
2,861 |
(9,153) | ||||||||||
Total costs and expenses |
165,679 |
594,801 |
636,660 |
1,488,088 | ||||||||||
Operating loss |
(58,276) |
(468,573) |
(351,887) |
(1,084,887) | ||||||||||
Interest expense: |
||||||||||||||
Incurred |
23,693 |
28,754 |
81,280 |
77,816 | ||||||||||
Capitalized |
(75) |
(2,203) |
(520) |
(6,010) | ||||||||||
Gain on exchange of debt |
123,960 |
- |
123,960 |
- | ||||||||||
Other (income) expense, net |
(73) |
964 |
1,209 |
2,647 | ||||||||||
Income (loss) before income tax benefit |
42,139 |
(496,088) |
(309,896) |
(1,159,340) | ||||||||||
Income tax benefit |
(3,789) |
(18,520) |
(44,393) |
(166,228) | ||||||||||
Net income (loss) |
$ |
45,928 |
$ |
(477,568) |
$ |
(265,503) |
$ |
(993,112) | ||||||
Basic and diluted earnings (loss) per common share |
$ |
0.48 |
$ |
(6.29) |
$ |
(3.25) |
$ |
(13.08) | ||||||
Weighted average common shares outstanding |
92,243 |
75,932 |
81,748 |
75,900 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Three Months Ended |
||||||||||||
September 30, |
Variance | |||||||||||
2016 |
2015 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
1,791 |
1,973 |
(182) |
-9.2% | ||||||||
NGL (MBbls) |
372 |
389 |
(17) |
-4.4% | ||||||||
Oil and NGLs (MBbls) |
2,163 |
2,362 |
(199) |
-8.4% | ||||||||
Natural gas (MMcf) |
9,935 |
11,635 |
(1,700) |
-14.6% | ||||||||
Total oil and natural gas (MBoe) (1) |
3,819 |
4,302 |
(483) |
-11.2% | ||||||||
Total oil and natural gas (MMcfe) (1) |
22,912 |
25,810 |
(2,898) |
-11.2% | ||||||||
Average daily equivalent sales (MBoe/d) |
41.5 |
46.8 |
(5.3) |
-11.4% | ||||||||
Average daily equivalent sales (MMcfe/d) |
249.0 |
280.5 |
(31.5) |
-11.2% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
39.62 |
$ |
43.85 |
$ |
(4.23) |
-9.6% | |||||
NGLs ($/Bbl) |
18.02 |
16.74 |
1.28 |
7.6% | ||||||||
Oil and NGLs ($/Bbl) |
35.91 |
39.38 |
(3.47) |
-8.8% | ||||||||
Natural gas ($/Mcf) |
2.93 |
2.69 |
0.24 |
8.9% | ||||||||
Barrel of oil equivalent ($/Boe) |
27.97 |
28.92 |
(0.95) |
-3.3% | ||||||||
Natural gas equivalent ($/Mcfe) |
4.66 |
4.82 |
(0.16) |
-3.3% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
9.82 |
$ |
10.47 |
$ |
(0.65) |
-6.2% | |||||
Gathering and transportation costs and production taxes |
1.48 |
1.04 |
0.44 |
42.3% | ||||||||
Depreciation, depletion, amortization and accretion |
13.49 |
22.62 |
(9.13) |
-40.4% | ||||||||
General and administrative expenses |
3.32 |
3.84 |
(0.52) |
-13.5% | ||||||||
Adjusted EBITDA |
13.74 |
14.27 |
(0.53) |
-3.7% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.64 |
$ |
1.74 |
$ |
(0.10) |
-5.7% | |||||
Gathering and transportation costs and production taxes |
0.25 |
0.17 |
0.08 |
47.1% | ||||||||
Depreciation, depletion, amortization and accretion |
2.25 |
3.77 |
(1.52) |
-40.3% | ||||||||
General and administrative expenses |
0.55 |
0.64 |
(0.09) |
-14.1% | ||||||||
Adjusted EBITDA |
2.29 |
2.38 |
(0.09) |
-3.8% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Nine Months Ended |
||||||||||||
September 30, |
Variance | |||||||||||
2016 |
2015 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
5,532 |
5,776 |
(244) |
-4.2% | ||||||||
NGL (MBbls) |
1,180 |
1,241 |
(61) |
-4.9% | ||||||||
Oil and NGLs (MBbls) |
6,712 |
7,017 |
(305) |
-4.3% | ||||||||
Natural gas (MMcf) |
29,696 |
35,470 |
(5,774) |
-16.3% | ||||||||
Total oil and natural gas (MBoe) (1) |
11,661 |
12,928 |
(1,267) |
-9.8% | ||||||||
Total oil and natural gas (MMcfe) (1) |
69,967 |
77,569 |
(7,602) |
-9.8% | ||||||||
Average daily equivalent sales (MBoe/d) |
42.6 |
47.4 |
(4.8) |
-10.1% | ||||||||
Average daily equivalent sales (MMcfe/d) |
255.4 |
284.1 |
(28.7) |
-10.1% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
35.01 |
$ |
47.81 |
$ |
(12.80) |
-26.8% | |||||
NGLs ($/Bbl) |
15.85 |
17.57 |
(1.72) |
-9.8% | ||||||||
Oil and NGLs ($/Bbl) |
31.64 |
42.46 |
(10.82) |
-25.5% | ||||||||
Natural gas ($/Mcf) |
2.33 |
2.82 |
(0.49) |
-17.4% | ||||||||
Barrel of oil equivalent ($/Boe) |
24.15 |
30.78 |
(6.63) |
-21.5% | ||||||||
Natural gas equivalent ($/Mcfe) |
4.02 |
5.13 |
(1.11) |
-21.6% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
10.17 |
$ |
11.10 |
$ |
(0.93) |
-8.4% | |||||
Gathering and transportation costs and production taxes |
1.55 |
1.22 |
0.33 |
27.0% | ||||||||
Depreciation, depletion, amortization and accretion |
14.81 |
25.23 |
(10.42) |
-41.3% | ||||||||
General and administrative expenses |
3.89 |
4.41 |
(0.52) |
-11.8% | ||||||||
Adjusted EBITDA |
9.42 |
14.65 |
(5.23) |
-35.7% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.70 |
$ |
1.85 |
$ |
(0.15) |
-8.1% | |||||
Gathering and transportation costs and production taxes |
0.26 |
0.20 |
0.06 |
30.0% | ||||||||
Depreciation, depletion, amortization and accretion |
2.47 |
4.20 |
(1.73) |
-41.2% | ||||||||
General and administrative expenses |
0.65 |
0.74 |
(0.09) |
-12.2% | ||||||||
Adjusted EBITDA |
1.57 |
2.44 |
(0.87) |
-35.7% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Balance Sheets | |||||||
(Unaudited) | |||||||
September 30, |
December 31, | ||||||
2016 |
2015 | ||||||
(In thousands, except | |||||||
share data) | |||||||
Assets |
|||||||
Current assets: |
|||||||
Cash and cash equivalents |
$ |
73,351 |
$ |
85,414 | |||
Receivables: |
|||||||
Oil and natural gas sales |
35,772 |
35,005 | |||||
Joint interest and other |
17,688 |
22,012 | |||||
Total receivables |
53,460 |
57,017 | |||||
Prepaid expenses and other assets |
16,145 |
26,879 | |||||
Total current assets |
142,956 |
169,310 | |||||
Property and equipment – at cost: |
|||||||
Oil and natural gas properties and equipment (full cost method, of which $0 at September 30, 2016 and $18,595 at December 31, 2015 were excluded from amortization) |
7,937,338 |
7,902,494 | |||||
Furniture, fixtures and other |
20,898 |
20,802 | |||||
Total property and equipment |
7,958,236 |
7,923,296 | |||||
Less accumulated depreciation, depletion and amortization |
7,371,677 |
6,933,247 | |||||
Net property and equipment |
586,559 |
990,049 | |||||
Deferred income taxes |
12,395 |
27,595 | |||||
Restricted deposits for asset retirement obligations |
26,767 |
15,606 | |||||
Income tax receivables |
52,097 |
- | |||||
Other assets |
11,823 |
5,462 | |||||
Total assets |
$ |
832,597 |
$ |
1,208,022 | |||
Liabilities and Shareholders' Deficit |
|||||||
Current liabilities: |
|||||||
Accounts payable |
$ |
83,309 |
$ |
109,797 | |||
Undistributed oil and natural gas proceeds |
21,239 |
21,439 | |||||
Asset retirement obligations |
90,150 |
84,335 | |||||
Long-term debt |
8,763 |
- | |||||
Accrued liabilities |
19,573 |
11,922 | |||||
Total current liabilities |
223,034 |
227,493 | |||||
Long-term debt, less current portion |
1,014,221 |
1,196,855 | |||||
Asset retirement obligations, less current portion |
256,656 |
293,987 | |||||
Other liabilities |
16,683 |
16,178 | |||||
Commitments and contingencies |
- |
- | |||||
Shareholders' equity (deficit): |
|||||||
Common stock, $0.00001 par value; 200,000,000 shares authorized; 139,951,997 issued and 137,082,824 outstanding at September 30, 2016; 79,375,662 issued and 75,506,489 outstanding at December 31, 2015 |
1 |
1 | |||||
Additional paid-in capital |
537,496 |
423,499 | |||||
Retained earnings (deficit) |
(1,191,327) |
(925,824) | |||||
Treasury stock, at cost |
(24,167) |
(24,167) | |||||
Total shareholders' deficit |
(677,997) |
(526,491) | |||||
Total liabilities and shareholders' deficit |
$ |
832,597 |
$ |
1,208,022 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||||||||
Long-Term Debt and Debt Exchange | |||||||||||||
(Unaudited) | |||||||||||||
($ in thousands) | |||||||||||||
June 30, |
December 31, | ||||||||||||
September 30, 2016 |
2016 |
2015 | |||||||||||
PIK Payable/ |
|||||||||||||
Interest Payable/ |
Carrying |
Principal/ |
Principal/ | ||||||||||
Principal |
Other |
Value |
Other * |
Other * | |||||||||
Revolving Bank Credit Facility, |
|||||||||||||
due November 2018 |
$ - |
$ - |
$ - |
$ 148,000 |
$ - | ||||||||
11.00 % 1.5 Lien Term Loan, |
|||||||||||||
due November 2019 |
75,000 |
26,393 |
101,393 |
- |
- | ||||||||
9.00% Second Lien Term Loan, |
|||||||||||||
due May 2020 |
300,000 |
- |
300,000 |
300,000 |
300,000 | ||||||||
9.00%/10.75% Second Lien PIK Toggle Notes, |
|||||||||||||
due May 2020 |
159,763 |
64,142 |
223,905 |
- |
- | ||||||||
8.50%/10.00% Third Lien PIK Toggle Notes, |
|||||||||||||
due June 2021 |
142,031 |
71,416 |
213,447 |
- |
- | ||||||||
8.50% Unsecured Senior Notes, |
|||||||||||||
due June 2019 |
189,829 |
- |
189,829 |
900,000 |
900,000 | ||||||||
Subtotal |
866,623 |
161,951 |
1,028,574 |
1,348,000 |
1,200,000 | ||||||||
Debt premium, discount, issuance costs, |
|||||||||||||
net of amortization |
- |
(5,590) |
(5,590) |
(2,949) |
(3,145) | ||||||||
Total long-term debt |
866,623 |
156,361 |
1,022,984 |
1,345,051 |
1,196,855 | ||||||||
Current maturities of long-term debt |
- |
8,763 |
8,763 |
- |
- | ||||||||
Long term debt, less current maturities |
$ 866,623 |
$ 147,598 |
$ 1,014,221 |
$ 1,345,051 |
$ 1,196,855 |
* Amounts also equal carrying value of these dates. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||
Condensed Consolidated Statements of Cash Flows | ||||||||
(Unaudited) | ||||||||
Nine Months Ended |
||||||||
September 30, |
||||||||
2016 |
2015 |
|||||||
(In thousands) |
||||||||
Operating activities: |
||||||||
Net loss |
$ |
(265,503) |
$ |
(993,112) |
||||
Adjustments to reconcile net loss to net cash provided by (used in) operating activities: |
||||||||
Depreciation, depletion, amortization and accretion |
172,726 |
326,138 |
||||||
Ceiling test write-down of oil and natural gas properties |
279,063 |
954,850 |
||||||
Gain on exchange of debt |
(123,960) |
- |
||||||
Debt issuance costs write-off/amortization of debt items |
2,135 |
2,862 |
||||||
Share-based compensation |
7,642 |
8,313 |
||||||
Derivative (gain) loss |
2,861 |
(9,153) |
||||||
Cash receipts on derivative settlements |
4,746 |
2,139 |
||||||
Deferred income taxes |
15,484 |
(166,258) |
||||||
Asset retirement obligation settlements |
(56,167) |
(25,515) |
||||||
Changes in operating assets and liabilities |
(48,195) |
34,529 |
||||||
Net cash provided by (used in) operating activities |
(9,168) |
134,793 |
||||||
Investing activities: |
||||||||
Investment in oil and natural gas properties and equipment |
(24,062) |
(192,811) |
||||||
Changes in operating assets and liabilities associated with investing activities |
(37,400) |
(65,463) |
||||||
Proceeds from sales of assets |
1,500 |
- |
||||||
Purchases of furniture, fixtures and other |
(96) |
(1,185) |
||||||
Net cash used in investing activities |
(60,058) |
(259,459) |
||||||
Financing activities: |
||||||||
Borrowings of long-term debt - revolving bank credit facility |
340,000 |
263,000 |
||||||
Repayments of long-term debt - revolving bank credit facility |
(340,000) |
(445,000) |
||||||
Issuance of Second Lien Term Loan |
- |
297,000 |
||||||
Issuance of 1.5 Lien Term Loan |
75,000 |
- |
||||||
Debt exchange/issuance costs |
(17,920) |
(6,591) |
||||||
Other |
83 |
54 |
||||||
Net cash provided by financing activities |
57,163 |
108,463 |
||||||
Decrease in cash and cash equivalents |
(12,063) |
(16,203) |
||||||
Cash and cash equivalents, beginning of period |
85,414 |
23,666 |
||||||
Cash and cash equivalents, end of period |
$ |
73,351 |
$ |
7,463 |
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 (Loss) to Net (Loss) Excluding Special Items
"Net Loss Excluding Special Items" does not include the unrealized commodity derivative (gain) loss, write-off of debt issuance and other non-operating costs, a contingent assessment provision, ceiling test write-down of oil and natural gas properties, gain on exchange of debt and associated income tax adjustments. Net 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 |
Nine Months Ended |
|||||||||||||||
September 30, |
September 30, |
|||||||||||||||
2016 |
2015 |
2016 |
2015 |
|||||||||||||
(In thousands, except per share amounts) | ||||||||||||||||
(Unaudited) | ||||||||||||||||
Net income (loss) |
$ |
45,928 |
$ |
(477,568) |
$ |
(265,503) |
$ |
(993,112) |
||||||||
Unrealized commodity derivative (gain) loss |
412 |
(8,092) |
7,606 |
(7,014) |
||||||||||||
Write off of debt issuance and other non operating costs |
928 |
- |
3,699 |
1,973 |
||||||||||||
Contingent assessment provision |
- |
- |
- |
1,000 |
||||||||||||
Ceiling test write-down of oil and natural gas properties |
57,912 |
441,688 |
279,063 |
954,850 |
||||||||||||
Gain on exchange of debt |
(123,960) |
- |
(123,960) |
- |
||||||||||||
Income tax adjustment |
(3,789) |
(16,043) |
(23,796) |
(135,966) |
||||||||||||
Net loss excluding special items |
$ |
(22,569) |
$ |
(60,015) |
$ |
(122,891) |
$ |
(178,269) |
||||||||
Basic and diluted loss per common share, excluding special items |
$ |
(0.24) |
$ |
(0.79) |
$ |
(1.50) |
$ |
(2.35) |
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Reconciliation of Net Income (Loss) to Adjusted EBITDA
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative (gain) loss, write off of debt issuance and other non-operating costs, gain on exchange of debt, and a contingent assessment provision. 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 (loss), 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 consolidated net loss to consolidated EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Three Months Ended |
Nine Months Ended |
|||||||||||||||
September 30, |
September 30, |
|||||||||||||||
2016 |
2015 |
2016 |
2015 |
|||||||||||||
(In thousands) | ||||||||||||||||
(Unaudited) | ||||||||||||||||
Net income (loss) |
$ |
45,928 |
$ |
(477,568) |
$ |
(265,503) |
$ |
(993,112) |
||||||||
Income tax benefit |
(3,789) |
(18,520) |
(44,393) |
(166,228) |
||||||||||||
Net interest expense |
23,546 |
26,535 |
80,602 |
71,787 |
||||||||||||
Depreciation, depletion, amortization and accretion |
51,500 |
97,329 |
172,726 |
326,138 |
||||||||||||
Ceiling test write-down of oil and natural gas properties |
57,912 |
441,688 |
279,063 |
954,850 |
||||||||||||
EBITDA |
175,097 |
69,464 |
222,495 |
193,435 |
||||||||||||
Adjustments: |
||||||||||||||||
Unrealized commodity derivative (gain) loss |
412 |
(8,092) |
7,606 |
(7,014) |
||||||||||||
Write off of debt issuance and other non operating costs |
928 |
- |
3,699 |
1,973 |
||||||||||||
Gain on exchange of debt |
(123,960) |
- |
(123,960) |
- |
||||||||||||
Contingent assessment provision |
- |
- |
- |
1,000 |
||||||||||||
Adjusted EBITDA |
$ |
52,477 |
$ |
61,372 |
$ |
109,840 |
$ |
189,394 |
||||||||
Adjusted EBITDA Margin |
49% |
49% |
39% |
47% |
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Oct. 19, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its third quarter 2016 financial and operational results after the market closes on Wednesday, November 2. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Thursday, November 3 at 8:30 a.m. Eastern Time (7:30 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through November 10, 2016 by dialing 1-201-612-7415 and using the passcode 13648354. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Sept. 8, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) (the "Company") today announced the closing of its previously announced exchange offer and consent solicitation to eligible holders of its outstanding 8.500% Senior Notes due 2019 (the "Existing Notes") pursuant to the terms of the offering memorandum and consent solicitation statement, as amended, and the related letter of transmittal. The Company exchanged approximately $710.2 million, or approximately 78.9%, of the outstanding aggregate principal amount of Existing Notes pursuant to the terms of the exchange offer for approximately (i) 60.4 million shares of common stock, par value $0.00001 per share, of the Company (the "Shares"), (ii) $159.8 million aggregate principal amount of its new Senior Second Lien PIK Toggle Notes due 2020 (the "New Second Lien Notes") and (iii) $142.0 million aggregate principal amount of its new Senior Third Lien PIK Toggle Notes due 2021 (the "New Third Lien Notes" and, together with the New Second Lien Notes and the Shares, the "New Securities"). The Company also announced the closing of its new 1.5 lien secured term loan facility in the principal amount of $75.0 million (the "New Capital Financing"), the proceeds of which were used to repay a portion of the outstanding borrowings under the Company's first lien revolving bank credit facility and to pay expenses related to the exchange offer and the New Capital Financing.
Tracy W. Krohn, the Company's Chairman and Chief Executive Officer, stated, "We are pleased to announce the closing of the exchange transaction, which reduced overall outstanding indebtedness by $408 million before the New Capital Financing. In addition to improving liquidity and reducing interest expense, the Company is now in a better position to take advantage of upside opportunities in our quality asset base and benefit from the eventual upcycle in the market, as well as other opportunities."
The New Securities offered by the Company have not been registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws and, unless so registered, may not be offered or sold in the United States except pursuant to an applicable exemption from the registration requirements of the Securities Act and applicable state securities laws. The exchange offer and consent solicitation was not made to holders of Existing Notes in any jurisdiction in which the making or acceptance thereof would not be in compliance with the securities, blue sky or other laws of such jurisdiction. This press release is for informational purposes only and is not an offer to purchase, a solicitation of an offer to purchase or a solicitation of consents with respect to, any securities.
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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 and Section 21E of the Securities Exchange Act of 1934, as amended. These forward-looking statements reflect the Company's current views with respect to future events, based on what it believes 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 the Company's 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, 2015 and subsequent Form 10-Q reports found at www.sec.gov or at the Company's website at www.wtoffshore.com under the Investor Relations section. Investors are urged to consider closely the disclosures and risk factors in these reports.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Sept. 2, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) (the "Company") today announced the expiration and final results for its previously announced exchange offer and consent solicitation to eligible holders of its outstanding 8.500% Senior Notes due 2019 (the "Existing Notes") for up to (i) 76,590,000 shares of common stock, par value $0.00001 per share, of the Company (the "Shares"), (ii) $202.5 million aggregate principal amount of its new Senior Second Lien PIK Toggle Notes due 2020 (the "New Second Lien Notes") and (iii) $180.0 million aggregate principal amount of its new Senior Third Lien PIK Toggle Notes due 2021 (the "New Third Lien Notes" and, together with the New Second Lien Notes and the Shares, the "New Securities") pursuant to the terms of the offering memorandum and consent solicitation statement, as amended, and the related letter of transmittal (together, the "Offering Documents"). At a Special Meeting of the Company's shareholders held on September 1, 2016 (the "Special Meeting"), the increase in the Company's authorized common stock to 200,000,000 shares and the issuance of the Shares were approved. For more information regarding the Special Meeting results, please see the Company's Current Report on Form 8-K filed with the Securities and Exchange Commission on September 2, 2016.
The Company has been informed by the information agent for the exchange offer that, as of 5:00 p.m., New York City time, on September 1, 2016, a total of approximately $710.2 million, or approximately 78.9%, of the outstanding aggregate principal amount of Existing Notes were validly tendered. The Company has accepted for exchange all of the validly tendered Existing Notes. As a result, approximately 60.4 million Shares, $159.8 million aggregate principal amount of New Second Lien Notes and $142.0 million aggregate principal amount of New Third Lien Notes will be issued upon settlement of the exchange offer, which is expected to occur on or about September 7, 2016. In addition, the requisite consents were received to approve the proposed amendment to the indenture governing the Existing Notes.
The New Securities offered by the Company have not been registered under the Securities Act, or any state securities laws and, unless so registered, may not be offered or sold in the United States except pursuant to an applicable exemption from the registration requirements of the Securities Act and applicable state securities laws. The exchange offer and consent solicitation was not made to holders of Existing Notes in any jurisdiction in which the making or acceptance thereof would not be in compliance with the securities, blue sky or other laws of such jurisdiction. This press release is for informational purposes only and is not an offer to purchase, a solicitation of an offer to purchase or a solicitation of consents with respect to, any securities.
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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 and Section 21E of the Securities Exchange Act of 1934, as amended. These forward-looking statements reflect the Company's current views with respect to future events, based on what it believes 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 the Company's 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, 2015 and subsequent Form 10-Q reports found at www.sec.gov or at the Company's website at www.wtoffshore.com under the Investor Relations section. Investors are urged to consider closely the disclosures and risk factors in these reports.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Aug. 31, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) (the "Company") today announced the early participation results for its previously announced exchange offer and consent solicitation to eligible holders of its outstanding 8.500% Senior Notes due 2019 (the "Existing Notes") for up to (i) 76,590,000 shares of common stock, par value $0.00001 per share, of the Company (the "Shares"), (ii) $202.5 million aggregate principal amount of its new Senior Second Lien PIK Toggle Notes due 2020 (the "New Second Lien Notes") and (iii) $180.0 million aggregate principal amount of its new Senior Third Lien PIK Toggle Notes due 2021 (the "New Third Lien Notes" and, together with the New Second Lien Notes and the Shares, the "New Securities") pursuant to the terms of the offering memorandum and consent solicitation statement, as amended, and the related letter of transmittal (together, the "Offering Documents").
The Company has been informed by the information agent for the exchange offer that, as of 5:00 p.m., New York City time, on August 30, 2016, a total of approximately $710.2 million, or approximately 78.9%, of the outstanding aggregate principal amount of Existing Notes were validly tendered.
The exchange offer and consent solicitation will expire at 5:00 p.m., New York City time, on September 1, 2016, unless extended or earlier terminated by the Company. The act of tendering Existing Notes pursuant to the exchange offer constitutes a consent to the proposed amendment to the indenture governing the Existing Notes. The exchange offer is conditioned on the satisfaction or waiver of certain additional conditions, as described in the Offering Documents. The exchange offer and consent solicitation for the Existing Notes may be further amended, extended or terminated.
The exchange offer and consent solicitation is only being made, and copies of the Offering Documents will only be made available, to holders of the Existing Notes who complete and submit an eligibility form confirming that they are (1) "qualified institutional buyers" within the meaning of Rule 144A under the Securities Act of 1933, as amended (the "Securities Act"), or (2) not "U.S. persons" and are outside of the United States within the meaning of Regulation S under the Securities Act (such persons, "eligible holders"). Holders who desire to obtain and complete an eligibility form should contact the information agent, D.F. King & Co., Inc., at (877) 536-1561 (toll-free) or (212) 269-5550 (for banks and brokers), or via the following website: www.dfking.com/wti.
Eligible holders are urged to carefully read the Offering Documents before making any decision with respect to the exchange offer and consent solicitation. None of the Company, the sole dealer manager, the information agent or the exchange agent makes any recommendation as to whether eligible holders should tender or refrain from tendering their Existing Notes. Eligible holders must make their own decision as to whether to tender Existing Notes and, if so, the principal amount of Existing Notes to tender.
The New Securities offered by the Company have not been registered under the Securities Act, or any state securities laws and, unless so registered, may not be offered or sold in the United States except pursuant to an applicable exemption from the registration requirements of the Securities Act and applicable state securities laws. The exchange offer and consent solicitation is not being made to holders of Existing Notes in any jurisdiction in which the making or acceptance thereof would not be in compliance with the securities, blue sky or other laws of such jurisdiction. This press release is for informational purposes only and is not an offer to purchase, a solicitation of an offer to purchase or a solicitation of consents with respect to, any securities.
Evercore Group L.L.C. is acting as the sole dealer manager in the Exchange Offer.
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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 and Section 21E of the Securities Exchange Act of 1934, as amended. These forward-looking statements reflect the Company's current views with respect to future events, based on what it believes 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 the Company's 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, 2015 and subsequent Form 10-Q reports found at www.sec.gov or at the Company's website at www.wtoffshore.com under the Investor Relations section. Investors are urged to consider closely the disclosures and risk factors in these reports.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Aug. 16, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) (the "Company") today announced that, with respect to its previously announced exchange offer and consent solicitation to eligible holders of its outstanding 8.500% Senior Notes due 2019 (the "Existing Notes"), it has (i) extended the Early Participation Date to 5:00 p.m., New York City time, on August 30, 2016 (as extended, the "Early Participation Date"), (ii) eliminated the Minimum Tender Condition (as defined in the Offering Documents (as defined below)) and (iii) increased the maximum consideration being offered to (i) 76,590,000 shares of common stock, par value $0.00001 per share, of the Company (the "Shares") (increased from 62,100,000 Shares), (ii) $202.5 million aggregate principal amount of its new Senior Second Lien PIK Toggle Notes due 2020 (the "New Second Lien Notes") and (iii) $180.0 million aggregate principal amount of its new Senior Third Lien PIK Toggle Notes due 2021 (the "New Third Lien Notes" and, together with the New Second Lien Notes, the "New Notes"; the New Notes and the Shares, the "New Securities") pursuant to the terms of the offering memorandum and consent solicitation statement and the related letter of transmittal and consent, as amended by a supplement setting forth the modifications described above (together, the "Offering Documents"). The New Third Lien Notes will be issued in lieu of the unsecured Senior PIK Toggle Notes due 2021 described in the Offering Documents, regardless of the percentage of principal amount of Existing Notes that are tendered. Concurrently with the exchange offer, the Company is soliciting consents from holders of the Existing Notes to a proposed amendment to the indenture governing the Existing Notes in order to permit the issuance of the New Second Lien Notes and the New Third Lien Notes. The following table sets forth the increased consideration to be offered to eligible holders of the Existing Notes in the exchange offer:
Existing Notes to be Exchanged (CUSIP No. / ISIN) |
Aggregate Principal Amount Outstanding |
Total Exchange Consideration for each $1,000 Principal Amount of Existing Notes if Tendered Prior to or on the Early Participation Date |
Exchange Consideration for each $1,000 Principal Amount of Existing Notes if Tendered After the Early Participation Date | |||
8.500% Senior Notes due 2019 (92922P AC0 / US92922PAC05) |
$900,000,000 |
(i) 85.1 Shares; (ii) $225 principal amount of New Second Lien Notes; and (iii) $200 principal amount of New Third Lien Notes |
(i) 85.1 Shares; (ii) $200 principal amount of New Second Lien Notes; and (iii) $200 principal amount of New Third Lien Notes |
The total exchange consideration to be received by eligible holders of Existing Notes who validly tender their Existing Notes prior to the Early Participation Date will include an early tender premium equal to $25 principal amount of New Second Lien Notes per $1,000 principal amount of Existing Notes accepted for exchange.
For Existing Notes validly tendered after the Early Participation Date and on or before the Expiration Date (as defined below), the eligible holders of Existing Notes accepted for exchange will receive the exchange consideration set forth above, which does not include the early tender premium. Eligible holders of Existing Notes accepted for exchange will also receive a cash payment equal to the accrued and unpaid interest in respect of such Existing Notes from June 15, 2016 (the most recent interest payment date) to, but not including, the date the exchange offer is settled (the "Settlement Date"). Interest on the New Notes will accrue from the Settlement Date.
Certain holders of the Existing Notes (the "Participating Holders") entered into a Support Agreement, dated July 11, 2016 (the "Support Agreement"). Pursuant to the Support Agreement, the Participating Holders agreed to tender their Existing Notes in the exchange offer, subject to various conditions, including a limitation on the Company's ability to reduce the Minimum Tender Condition to a threshold lower than 85% of the aggregate principal amount of the outstanding Existing Notes (the "Threshold Limitation"). Certain of the Participating Holders have entered into an amendment to the Support Agreement (the "Amendment") whereby they have agreed to eliminate the Threshold Limitation. In addition, the Company has waived the Minimum Tender Condition that was originally set forth in the Offering Documents. Therefore, the exchange offer is no longer subject to the Minimum Tender Condition. The Amendment also provides for certain limitations on the Company's ability to consummate future exchanges or repurchases of the Existing Notes on terms more favorable than the terms provided in the exchange offer for the life of the Existing Notes.
As previously announced, the exchange offer and consent solicitation will expire at 5:00 p.m., New York City time, on September 1, 2016, unless extended or earlier terminated by the Company (the "Expiration Date"). The right to withdraw tenders of Existing Notes and related consents terminated at 5:00 p.m., New York City time, on August 8, 2016 (the "Withdrawal Deadline"). Accordingly, Existing Notes and related consents tendered before the Withdrawal Deadline remain tendered and may not be withdrawn or revoked, except in certain limited circumstances where additional withdrawal rights are required by law. Tenders submitted after the Withdrawal Deadline and on or before the Expiration Date in the exchange offer and related consents will be irrevocable, except in the same limited circumstances. The act of tendering Existing Notes pursuant to the exchange offer constitutes a consent to the proposed amendment to the indenture governing the Existing Notes. The exchange offer is conditioned on the satisfaction or waiver of certain additional conditions, as described in the Offering Documents. The exchange offer and consent solicitation for the Existing Notes may be further amended, extended or terminated.
The exchange offer and consent solicitation is only being made, and copies of the Offering Documents will only be made available, to holders of the Existing Notes who complete and submit an eligibility form confirming that they are (1) "qualified institutional buyers" within the meaning of Rule 144A under the Securities Act of 1933, as amended (the "Securities Act") or (2) not "U.S. persons" and are outside of the United States within the meaning of Regulation S under the Securities Act (such persons, "eligible holders"). Holders who desire to obtain and complete an eligibility form should contact the information agent, D.F. King & Co., Inc., at (877) 536-1561 (toll-free) or (212) 269-5550 (for banks and brokers), or via the following website: www.dfking.com/wti.
Eligible holders are urged to carefully read the Offering Documents before making any decision with respect to the exchange offer and consent solicitation. None of the Company, the sole dealer manager, the information agent or the exchange agent makes any recommendation as to whether eligible holders should tender or refrain from tendering their Existing Notes. Eligible holders must make their own decision as to whether to tender Existing Notes and, if so, the principal amount of Existing Notes to tender.
The New Securities offered by the Company have not been registered under the Securities Act, or any state securities laws and, unless so registered, may not be offered or sold in the United States except pursuant to an applicable exemption from the registration requirements of the Securities Act and applicable state securities laws. The exchange offer and consent solicitation is not being made to holders of Existing Notes in any jurisdiction in which the making or acceptance thereof would not be in compliance with the securities, blue sky or other laws of such jurisdiction. This press release is for informational purposes only and is not an offer to purchase, a solicitation of an offer to purchase or a solicitation of consents with respect to, any securities.
Evercore Group L.L.C. is acting as the sole dealer manager in the Exchange Offer.
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 approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 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 and Section 21E of the Securities Exchange Act of 1934, as amended. These forward-looking statements reflect the Company's current views with respect to future events, based on what it believes 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 the Company's 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, 2015 and subsequent Form 10-Q reports found at www.sec.gov or at the Company's website at www.wtoffshore.com under the Investor Relations section. Investors are urged to consider closely the disclosures and risk factors in these reports.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
lelliott@dennardlascar.com |
investorrelations@wtoffshore.com | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Aug. 8, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today announced that a Special Meeting of Shareholders of W&T Offshore will be held at 8 a.m. Central Time on Thursday, September 1, 2016, at the offices of the Company, Nine Greenway Plaza, Suite 300, Houston, Texas 77046. Shareholders of record at the close of business on August 4, 2016 are entitled to receive notice of the meeting and have the right to vote their shares of W&T Offshore common stock they held as of that date at the Special Meeting and at any reconvened meeting following any adjournment or postponement of the meeting.
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. For more information on W&T Offshore, please visit our website at www.wtoffshore.com
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, July 12, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its second quarter 2016 financial and operational results after the market closes on Thursday, August 4. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Friday August 5 at 9:30 a.m. Eastern Time (8:30 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through August 12 by dialing 1-201-612-7415 and using the passcode 13639967. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 850,000 gross acres, including approximately 500,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. For more information on W&T Offshore, please visit our website at www.wtoffshore.com.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, Aug. 4, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its second quarter 2016 operations and financial results, as well as its 2016 third quarter and full year production and expense guidance. Some of the key items and subsequent events include:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "The prolonged weakness in commodity prices has impacted our cash flow and liquidity, and restricted our ability to fund current and future drilling activity and debt obligations. As a result, we have tendered an offer to all qualifying holders of our 8.50% Senior Notes for an exchange to reduce our outstanding indebtedness, preserve liquidity, reduce interest expense and increase our ability to comply with our debt covenants and provide necessary funding for capital investments. We believe that we have a quality asset base with upside opportunities and an outstanding team of employees working hard to make W&T a success. Our objective is to prudently manage our balance sheet, assets and expenses, and position the Company to benefit from the eventual upcycle in the market."
Production, Revenues and Price: For the second quarter of 2016, our oil production was 1.8 million barrels, down 3.9% from the second quarter of 2015. NGL production was 450,900 barrels, up 10.5% from the second quarter of 2015, which includes a 20,714 barrel positive out of period adjustment related to ethane production (the ethane was sold as a product by the operator of the gas plant rather than reinjected into the natural gas stream). Natural gas production was 9.7 billion cubic feet ("Bcf") for the second quarter of 2016, down 15.6% from the second quarter of 2015. Our combined total production was 3.9 million barrels of oil equivalent ("MMBoe") in the second quarter of 2016, down 7.8% from the second quarter of 2015. Production was lower in the second quarter of 2016 compared to the second quarter of 2015 due to natural production declines, pipeline outages, field maintenance and the loss of production as a result of the sale of our Yellow Rose field in October 2015, partially offset by oil production additions from the development of certain deepwater fields within the last year.
During the quarter we experienced production deferrals attributable to third-party pipeline outages, operational issues, and maintenance, which occurred at Ship Shoal 349 (Mahogany), East Cameron 321 A and other locations. We estimate production deferrals reduced our quarterly production by approximately 0.5 MMBoe during the second quarter of 2016 compared to 0.7 million MMBoe for the second quarter of 2015.
Revenues for the second quarter of 2016 were $99.7 million compared to $149.1 million in the second quarter of 2015. The decrease in revenues was primarily due to the steep decline in commodity prices, combined with modestly lower production. Our average realized crude oil sales price was down $17.52 per barrel, or 30.9%, between the two quarters. NGLs prices declined 18.9%, or $3.62 per barrel and natural gas prices were lower by $0.69 per Mcf, or 25.2%, from the second quarter of 2015. During the second quarter of 2016, our average realized sales price for oil was $39.11 per barrel, $15.56 per barrel for NGLs and $2.05 per Mcf for natural gas. On a combined basis, we sold 42,864 Boe per day at an average realized sales price of $25.28 per Boe compared to 46,497 Boe per day sold at an average realized sales price of $34.83 per Boe in the second quarter of 2015.
West Texas Intermediate ("WTI") crude oil prices averaged $45.46 per barrel for the second quarter of 2016 compared to our average realized crude oil price of $39.11 per barrel. WTI is frequently used to value domestically produced crude oil, and the majority of our oil production is priced using the spot price for WTI as a base price, then adjusted for the type and quality of crude oil and other factors. Just like crude oil prices, the differentials for our offshore crude oil have also experienced significant volatility. For example, the monthly average differentials of WTI crude oil prices versus Light Louisiana Sweet ("LLS"), Heavy Louisiana Sweet ("HLS") and Poseidon crude oil prices for the second quarter of 2016 were a positive $2.04 and $1.23, and a negative $3.68 per barrel, respectively. The majority of our crude oil is priced similar to Poseidon and, therefore, is experiencing negative differentials. In addition, a few of our crude oil fields have a negative quality bank adjustment due to crude oil quality which reduces our crude oil price realizations.
Lease Operating Expenses: LOE, which includes base lease operating expenses, insurance premiums, workovers, and maintenance expenses on our facilities decreased $8.5 million, or 18.9%, to $36.6 million in the second quarter of 2016 compared to the second quarter of 2015. On a per Boe basis, lease operating expenses decreased to $9.39 per Boe in the second quarter of 2016, a 12.0% reduction compared to $10.67 per Boe in the second quarter of 2015. On a component basis, base lease operating expenses decreased $3.8 million, workover expense decreased $2.3 million, insurance premiums decreased $1.6 million and facilities maintenance decreased $1.0 million. Base lease operating expenses decreased primarily due to lower costs from service providers and the sale of the Yellow Rose field in October 2015, partially offset by increases in expenses related to our new deepwater fields at Dantzler and Big Bend and lower production handling fees (cost offsets) at our Mississippi Canyon 243 field (Matterhorn). The decrease in workover costs was primarily due to the sale of the Yellow Rose field and reduced activities offshore.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for ARO, decreased to $14.74 per Boe for the second quarter of 2016 from $24.42 per Boe for the second quarter of 2015. On a nominal basis, DD&A decreased to $57.5 million for the second quarter of 2016 from $103.3 million for the second quarter of 2015 due to a decrease in the DD&A rate per Boe and lower production volumes. The DD&A rate per Boe decreased primarily due to the ceiling test write-downs recorded in 2015 and the first quarter of 2016 (the second quarter 2016 ceiling test write-down will not affect the DD&A rate until the third quarter of 2016), the proceeds from the sale of the Yellow Rose field and the decrease in associated future development costs. Other factors affecting the DD&A rate are lower net proved reserves, the general reduction in the costs of goods and services and lower capital expenditures in relation to DD&A expense, which lowered the full-cost pool subject to DD&A.
Ceiling test write-down of oil and natural gas properties: For the second quarter of 2016, we recorded a non-cash ceiling test write-down of $104.6 million as the book value of our oil and natural gas properties exceeded the ceiling test limitation. The write-down resulted from a significant reduction in the market value of all three commodities we sell. For the second quarter of 2015, the ceiling test write-down was $252.8 million.
General and Administrative Expenses ("G&A"): G&A decreased $3.5 million, or 17.8% to $16.2 million for the second quarter of 2016 compared to the second quarter of 2015. The decrease was primarily due to decreases in headcount related expenses (salaries, benefits, contractors, etc.), partially offset by higher legal costs. G&A on a per BOE basis was $4.16 Boe for the second quarter of 2016 compared to $4.67 per Boe for the second quarter of 2015.
Derivatives: For the second quarter of 2016, we recorded a $4.9 million net derivative loss on derivative contracts for crude oil and natural gas as increased prices for crude oil and natural gas resulted in reversal of previously recorded gains. For the second quarter of 2015, there was a $1.1 million net derivative loss recorded. A report providing our commodity derivative positions is posted to our website.
Income Tax Benefit: Our income tax benefit for the second quarter of 2016 and 2015 was $35.7 million and $44.1 million, respectively, with the change attributable primarily to changes in the pre-tax loss and changes in the valuation allowance recorded for the respective periods. Our annualized effective tax rate for the second quarter of 2016 and 2015 was 22.8% and 14.5%, respectively, and differs from the federal statutory rate of 35% primarily due to recording and adjusting a valuation allowance related to federal and state deferred tax assets. During the three months ended June 30, 2016 and 2015, we recorded valuation allowances of $22.3 million and $62.9 million, respectively, related to federal and state deferred tax assets. Deferred tax assets are recorded related to net operating losses and temporary differences between the book and tax basis of assets and liabilities expected to generate tax deductions in future periods. The realization of these assets depends on recognition of sufficient future taxable income in specific tax jurisdictions in which those temporary differences or net operating losses are deductible. In assessing the need for a valuation allowance on our deferred tax assets, we consider whether it is more likely than not that some portion or all of them will not be realized.
Income Tax Receivable: As of June 30, 2016, we recorded a current income tax receivable of $5.6 million and non-current income tax receivables of $52.1 million. For the current income tax receivable, the amount is comprised principally of a net operating loss ("NOL") claim for 2015 carried back to 2005 filed on Form 1139, Corporation Application for Tentative Refund. For the net amount classified as non-current income tax receivables, our NOL claims for the years 2012, 2013 and 2014 were carried back to the years 2003, 2004, 2007, 2010 and 2011 filed on Form 1120X, U.S. Corporation Income Tax Return. These carryback claims are made pursuant to Internal Revenue Code ("IRC") Section 172(f) which permits certain platform dismantlement, well abandonment and site clearance costs to be carried back 10 years. The refund claims filed on Form 1120X will require a review by the Congressional Joint Committee on Taxation and are accordingly classified as non-current.
Net Loss & Loss Per Share: We reported a net loss for the second quarter of 2016 of ($120.9) million, or ($1.58) per common share, compared to net loss of ($260.4) million, or ($3.43) per common share, during the same period in 2015. Excluding special items (including the ceiling test write-down of oil and natural gas properties, write off of debt issuance and other non-operating costs and an unrealized commodity derivative loss, net of applicable federal income tax at the effective tax rate for the periods presented), our net loss for the second quarter of 2016 was ($35.8) million, or ($0.47) per common share, compared to second quarter 2015 net loss of ($40.9) million, or ($0.54) per common share. Operating results for the second quarter of 2016, excluding special items, were down primarily due to a $49.4 million decrease in revenues primarily driven by a 27.4% decline in our realized prices, partially offset by an $11.1 million decrease in operating costs and a $45.8 million decrease in DD&A.
See the "Reconciliation of Net Loss to Net Loss 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, Adjusted EBITDA and Liquidity: EBITDA, Adjusted EBITDA, and Adjusted EBITDA margin are non-GAAP measures and are defined in the "Non-GAAP Financial Measures" section at the end of this news release.
Net cash used in operating activities for the first six months of 2016 was $11.3 million compared to net cash provided by operating activities of $80.9 million for the same period in 2015.
Cash flows from operating activities, before changes in working capital and asset retirement obligations ("ARO") settlements and adjusted for income taxes (most all of which are non-cash), were $6.5 million in the first six months of 2016, compared to $87.6 million generated over the same period in 2015. Cash flows declined as revenues were $99.6 million lower in the 2016 period compared to the 2015 period while operating expenses were $24.1 million lower over the same time period. Asset retirement obligation settlements totaled $25.2 million in the first six months of 2016.
Adjusted EBITDA for the second quarter of 2016 was $40.8 million, down from $79.7 million generated over the same period in 2015. Our Adjusted EBITDA margin was 41% in the 2016 period compared to 53% in the 2015 period.
At June 30, 2016, we had a cash balance of $171.8 million and had $1.1 million of availability under our revolving bank credit facility. Also at June 30, 2016, borrowings outstanding under the revolving bank credit facility were in conformity with the borrowing base limitation.
2016 Capital Expenditures Update: Our capital expenditures on an accrual basis for the first six months of 2016 were $17.7 million ($51.8 million on a cash basis) compared to $151.0 million ($201.8 million on a cash basis) for the first six months of 2015. In 2016, the substantial majority of our capital expenditures were directed at completion activities of the Ewing Bank 954 A-8 well in the amount of $10.0 million. The remainder of the expenditures was associated with recompletions, other development activities and seismic.
Our capital expenditure budget for 2016 remains set at a level well below prior year levels. Our plug and abandonment activities for 2016 are currently estimated to total $76 million ($91.3 million over the next twelve months) and are expected to be funded with cash on hand and cash flow from operating activities.
BOEM Matters: In February and March, 2016, the Company received several orders from the Bureau of Ocean Energy Management ("BOEM") demanding that the Company provide additional financial security on certain Federal offshore oil and gas leases, rights of way ("ROW") and rights of use and easement ("RUE"). The outstanding orders total $260.8 million. We have filed appeals with the Interior Board of Land Appeals ("IBLA") regarding these orders. The IBLA, acknowledging that the BOEM and the Company were seeking to resolve the BOEM orders through settlement discussions, stayed the effectiveness of the orders until June 30, 2016. Because settlement discussions were ongoing, on June 30, 2016, the IBLA again stayed the effectiveness of the orders until August 31, 2016. We continue to have discussions with BOEM regarding these matters.
In July 2016, the BOEM issued Notice to Lessee ("NTL") No. 2016-N01, effective September 12, 2016, related to obligations for decommissioning activities on the Outer Continental Shelf ("OCS"), to clarify the procedures and guidelines that BOEM Regional Directors use to determine if and when additional security may be required for OCS leases, ROW, and RUE. This NTL supersedes and replaces NTL No. 2008-N07. Among other things, the NTL eliminates the "waiver exemption" currently allowed by the BOEM, whereby lessees on the OCS meeting certain financial strength and reliability criteria are exempted from posting bonds or other acceptable financial assurances for such lessee's decommissioning obligations. Under the new NTL, qualifying operators may self-insure for only an amount that is no more than 10% of their tangible net worth. In addition, the NTL implements a phase-in period for establishing compliance with additional security obligations for certain properties, whereby lessees may seek compliance with its additional security requirements under a "tailored plan" that is approved by the BOEM and would require securing phased in compliance in three approximately equal installments during a one-year period from the date of the BOEM approval of the tailored plan. Additional security for sole liability properties (those leases, ROWs or RUEs where there are no co-lessees or other grant holders or prior interest holders who may be liable to the BOEM) may not be phased in.
Exchange Offer: On July 25, 2016, we announced commencement of an exchange offer and consent solicitation to certain eligible holders of our outstanding 8.50% Senior Notes for up to (i) 62,100,000 shares of common stock of the Company, (ii) $202.5 million aggregate principal amount of its new Senior Second Lien PIK Toggle Notes due 2020 and (iii) $180.0 million aggregate principal amount of its new Senior PIK Toggle Notes due 2021. Concurrently with the exchange offer, the Company is soliciting consents from holders of the 8.50% Senior Notes to adopt certain proposed amendments to the indenture under which the 8.50% Senior Notes were issued.
The exchange offer, which expires on September 1, 2016 subject to extension, is conditioned on the satisfaction or waiver of certain additional conditions, including, among other things, (i) stockholder approval related to the increase in the number of authorized shares of the Company's common stock and the issuance of the shares of common stock in the exchange offer, which our majority stockholder and chief executive officer and chairman, Mr. Tracy W. Krohn, has stated he intends to approve, (ii) receipt of requisite lender consents to an amendment to our bank credit facility to permit, among other things, the exchange offer, and (iii) a minimum of 95%, or $855.0 million, of the 8.50% Senior Notes being tendered as of the expiration date together with requisite consents having been obtained, which tender condition may be waived, in the Company's discretion, provided 85%, or $765.0 million, of the 8.50% Senior Notes are tendered as of the expiration date. To the extent less than 90% in principal amount of the outstanding 8.50% Senior Notes are validly tendered and accepted for exchange, the new unsecured notes will instead be issued as secured by third-priority liens on substantially all of the Company's and its subsidiary guarantors' assets that secure the Company's revolving bank credit facility. The exchange offer and consent solicitation for the 8.50% Senior Notes may be amended, extended or terminated.
This press release is for informational purposes only and is not an offer to purchase or exchange, a solicitation of an offer to purchase or exchange or a solicitation of consents with respect to, any securities of the Company. The securities offered by the Company to eligible holders of 8.50% Senior Notes in the exchange offer described herein have not been registered under the Securities Act of 1933, as amended (the "Securities Act"), or any state securities laws and, unless so registered, may not be offered or sold in the United States except pursuant to an applicable exemption from the registration requirements of the Securities Act and applicable state securities laws. The exchange offer described herein is not being made to holders of 8.50% Senior Notes in any jurisdiction in which the making or acceptance thereof would not be in compliance with the securities, blue sky or other laws of such jurisdiction.
Third Quarter and Full Year 2016 Outlook
Our guidance for the third quarter and full year 2016 is provided in the table below and 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."
Third Quarter |
Prior Full Year |
Revised Full Year | |||
Production |
2016 |
2016 |
2016 | ||
Oil and NGLs (MMBbls) |
1.9 - 2.1 |
8.5 - 9.3 |
8.5 - 9.3 | ||
Natural gas (Bcf) |
9.2 - 10.1 |
37.9 - 41.9 |
37.9 - 41.9 | ||
Total (Bcf) |
20.3 - 22.4 |
88.8 - 98.2 |
88.8 - 98.2 | ||
Total (MMBoe) |
3.4 - 3.7 |
14.8 - 16.4 |
14.8 - 16.4 | ||
Operating Expenses |
Third Quarter |
Prior Full Year |
Revised Full Year | ||
($ in million) |
2016 |
2016 |
2016 | ||
Lease operating expenses |
$45 - $50 |
$166 - $184 |
$166 - $184 | ||
Gathering, transportation & production taxes |
$6 - $7 |
$22 - $24 |
$22 - $24 | ||
General and administrative |
$14 - $16 |
$61 - $68 |
$61 - $68 | ||
Income tax rate |
5.9% |
5.4% |
10.7% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Friday, August 5, 2016, at 9:30 a.m. Eastern 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 approximately two hours after the end of the call until August 12, 2016 and may be accessed by calling 201-612-7415 and using the passcode 13635554.
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 750,000 gross acres, including approximately 450,000 gross acres on the Gulf of Mexico Shelf and approximately 300,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. For more information on W&T Offshore, please visit our 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, 2015 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||||||||
Condensed Consolidated Statements of Income (Loss) | |||||||||||||
(Unaudited) | |||||||||||||
Three Months Ended |
Six Months Ended | ||||||||||||
June 30, |
June 30, | ||||||||||||
2016 |
2015 |
2016 |
2015 | ||||||||||
(In thousands, except per share data) | |||||||||||||
Revenues |
$ |
99,655 |
$ |
149,066 |
$ |
177,370 |
$ |
276,973 | |||||
Operating costs and expenses: |
|||||||||||||
Lease operating expenses |
36,622 |
45,130 |
81,091 |
98,461 | |||||||||
Gathering, transportation costs and production taxes |
6,768 |
5,793 |
12,386 |
11,254 | |||||||||
Depreciation, depletion, amortization and accretion |
57,493 |
103,342 |
121,226 |
228,809 | |||||||||
Ceiling test write-down of oil and natural gas properties |
104,592 |
252,772 |
221,151 |
513,162 | |||||||||
General and administrative expenses |
16,235 |
19,757 |
32,678 |
40,523 | |||||||||
Derivative loss |
4,942 |
1,078 |
2,449 |
1,078 | |||||||||
Total costs and expenses |
226,652 |
427,872 |
470,981 |
893,287 | |||||||||
Operating loss |
(126,997) |
(278,806) |
(293,611) |
(616,314) | |||||||||
Interest expense: |
|||||||||||||
Incurred |
29,773 |
26,116 |
57,587 |
49,062 | |||||||||
Capitalized |
(102) |
(2,024) |
(445) |
(3,807) | |||||||||
Other (income) expense, net |
(24) |
1,685 |
1,282 |
1,683 | |||||||||
Loss before income tax benefit |
(156,644) |
(304,583) |
(352,035) |
(663,252) | |||||||||
Income tax benefit |
(35,722) |
(44,134) |
(40,604) |
(147,708) | |||||||||
Net loss |
$ |
(120,922) |
$ |
(260,449) |
$ |
(311,431) |
$ |
(515,544) | |||||
Basic and diluted loss per common share |
$ |
(1.58) |
$ |
(3.43) |
$ |
(4.07) |
$ |
(6.79) | |||||
Weighted average common shares outstanding |
76,457 |
75,910 |
76,443 |
75,884 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||||||
Condensed Operating Data | |||||||||||
(Unaudited) | |||||||||||
Three Months Ended |
|||||||||||
June 30, |
Variance | ||||||||||
2016 |
2015 |
Variance |
Percentage(2) | ||||||||
Net sales volumes: |
|||||||||||
Oil (MBbls) |
1,835 |
1,909 |
(74) |
-3.9% | |||||||
NGL (MBbls) |
451 |
408 |
43 |
10.5% | |||||||
Oil and NGLs (MBbls) |
2,286 |
2,317 |
(31) |
-1.3% | |||||||
Natural gas (MMcf) |
9,690 |
11,486 |
(1,796) |
-15.6% | |||||||
Total oil and natural gas (MBoe) (1) |
3,901 |
4,231 |
(330) |
-7.8% | |||||||
Total oil and natural gas (MMcfe) (1) |
23,404 |
25,388 |
(1,984) |
-7.8% | |||||||
Average daily equivalent sales (MBoe/d) |
42.9 |
46.5 |
(3.6) |
-7.8% | |||||||
Average daily equivalent sales (MMcfe/d) |
257.2 |
279.0 |
(21.8) |
-7.8% | |||||||
Average realized sales prices: |
|||||||||||
Oil ($/Bbl) |
$ |
39.11 |
$ |
56.63 |
$ |
(17.52) |
-30.9% | ||||
NGLs ($/Bbl) |
15.56 |
19.18 |
(3.62) |
-18.9% | |||||||
Oil and NGLs ($/Bbl) |
34.46 |
50.03 |
(15.57) |
-31.1% | |||||||
Natural gas ($/Mcf) |
2.05 |
2.74 |
(0.69) |
-25.2% | |||||||
Barrel of oil equivalent ($/Boe) |
25.28 |
34.83 |
(9.55) |
-27.4% | |||||||
Natural gas equivalent ($/Mcfe) |
4.21 |
5.81 |
(1.60) |
-27.5% | |||||||
Average per Boe ($/Boe): |
|||||||||||
Lease operating expenses |
$ |
9.39 |
$ |
10.67 |
$ |
(1.28) |
-12.0% | ||||
Gathering and transportation costs and production taxes |
1.74 |
1.37 |
0.37 |
27.0% | |||||||
Depreciation, depletion, amortization and accretion |
14.74 |
24.42 |
(9.68) |
-39.6% | |||||||
General and administrative expenses |
4.16 |
4.67 |
(0.51) |
-10.9% | |||||||
Adjusted EBITDA |
10.46 |
18.83 |
(8.37) |
-44.5% | |||||||
Average per Mcfe ($/Mcfe): |
|||||||||||
Lease operating expenses |
$ |
1.56 |
$ |
1.78 |
$ |
(0.22) |
-12.4% | ||||
Gathering and transportation costs and production taxes |
0.29 |
0.23 |
0.06 |
26.1% | |||||||
Depreciation, depletion, amortization and accretion |
2.46 |
4.07 |
(1.61) |
-39.6% | |||||||
General and administrative expenses |
0.69 |
0.78 |
(0.09) |
-11.5% | |||||||
Adjusted EBITDA |
1.74 |
3.14 |
(1.40) |
-44.6% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||||||
Condensed Operating Data | |||||||||||
(Unaudited) | |||||||||||
Six Months Ended |
|||||||||||
June 30, |
Variance | ||||||||||
2016 |
2015 |
Variance |
Percentage(2) | ||||||||
Net sales volumes: |
|||||||||||
Oil (MBbls) |
3,740 |
3,803 |
(63) |
-1.7% | |||||||
NGL (MBbls) |
809 |
851 |
(42) |
-4.9% | |||||||
Oil and NGLs (MBbls) |
4,549 |
4,654 |
(105) |
-2.3% | |||||||
Natural gas (MMcf) |
19,761 |
23,835 |
(4,074) |
-17.1% | |||||||
Total oil and natural gas (MBoe) (1) |
7,843 |
8,627 |
(784) |
-9.1% | |||||||
Total oil and natural gas (MMcfe) (1) |
47,055 |
51,760 |
(4,705) |
-9.1% | |||||||
Average daily equivalent sales (MBoe/d) |
43.1 |
47.7 |
(4.6) |
-9.6% | |||||||
Average daily equivalent sales (MMcfe/d) |
258.5 |
286.0 |
(27.5) |
-9.6% | |||||||
Average realized sales prices: |
|||||||||||
Oil ($/Bbl) |
$ |
32.80 |
$ |
49.86 |
$ |
(17.06) |
-34.2% | ||||
NGLs ($/Bbl) |
14.85 |
17.94 |
(3.09) |
-17.2% | |||||||
Oil and NGLs ($/Bbl) |
29.61 |
44.02 |
(14.41) |
-32.7% | |||||||
Natural gas ($/Mcf) |
2.03 |
2.88 |
(0.85) |
-29.5% | |||||||
Barrel of oil equivalent ($/Boe) |
22.29 |
31.71 |
(9.42) |
-29.7% | |||||||
Natural gas equivalent ($/Mcfe) |
3.71 |
5.28 |
(1.57) |
-29.7% | |||||||
Average per Boe ($/Boe): |
|||||||||||
Lease operating expenses |
$ |
10.34 |
$ |
11.41 |
$ |
(1.07) |
-9.4% | ||||
Gathering and transportation costs and production taxes |
1.58 |
1.30 |
0.28 |
21.5% | |||||||
Depreciation, depletion, amortization and accretion |
15.46 |
26.52 |
(11.06) |
-41.7% | |||||||
General and administrative expenses |
4.17 |
4.70 |
(0.53) |
-11.3% | |||||||
Adjusted EBITDA |
7.31 |
14.84 |
(7.53) |
-50.7% | |||||||
Average per Mcfe ($/Mcfe): |
|||||||||||
Lease operating expenses |
$ |
1.72 |
$ |
1.90 |
$ |
(0.18) |
-9.5% | ||||
Gathering and transportation costs and production taxes |
0.26 |
0.22 |
0.04 |
18.2% | |||||||
Depreciation, depletion, amortization and accretion |
2.58 |
4.42 |
(1.84) |
-41.6% | |||||||
General and administrative expenses |
0.69 |
0.78 |
(0.09) |
-11.5% | |||||||
Adjusted EBITDA |
1.22 |
2.47 |
(1.25) |
-50.6% |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||
Condensed Consolidated Balance Sheets | ||||||
(Unaudited) | ||||||
June 30, |
December 31, | |||||
2016 |
2015 | |||||
(In thousands, except | ||||||
share data) | ||||||
Assets |
||||||
Current assets: |
||||||
Cash and cash equivalents |
$ |
171,824 |
$ |
85,414 | ||
Receivables: |
||||||
Oil and natural gas sales |
34,841 |
35,005 | ||||
Joint interest and other |
20,145 |
22,012 | ||||
Income taxes |
5,599 |
- | ||||
Total receivables |
60,585 |
57,017 | ||||
Prepaid expenses and other assets |
18,258 |
26,879 | ||||
Total current assets |
250,667 |
169,310 | ||||
Property and equipment – at cost: |
||||||
Oil and natural gas properties and equipment (full cost method, of which $5,267 at June 30, 2016 and $18,595 at December 31, 2015 were excluded from amortization) |
7,901,252 |
7,902,494 | ||||
Furniture, fixtures and other |
20,873 |
20,802 | ||||
Total property and equipment |
7,922,125 |
7,923,296 | ||||
Less accumulated depreciation, depletion and amortization |
7,266,289 |
6,933,247 | ||||
Net property and equipment |
655,836 |
990,049 | ||||
Deferred income taxes |
8,463 |
27,595 | ||||
Restricted deposits for asset retirement obligations |
26,409 |
15,606 | ||||
Income tax receivables, non-current |
52,097 |
- | ||||
Other assets |
4,882 |
5,462 | ||||
Total assets |
$ |
998,354 |
$ |
1,208,022 | ||
Liabilities and Shareholders' Equity (Deficit) |
||||||
Current liabilities: |
||||||
Accounts payable |
$ |
92,852 |
$ |
109,797 | ||
Undistributed oil and natural gas proceeds |
20,659 |
21,439 | ||||
Asset retirement obligations |
91,296 |
84,335 | ||||
Accrued liabilities |
12,011 |
11,922 | ||||
Total current liabilities |
216,818 |
227,493 | ||||
Long-term debt, less current maturities |
1,345,051 |
1,196,855 | ||||
Asset retirement obligations, less current portion |
252,826 |
293,987 | ||||
Other liabilities |
16,462 |
16,178 | ||||
Commitments and contingencies |
- |
- | ||||
Shareholders' equity (deficit): |
||||||
Common stock, $0.00001 par value; 118,330,000 shares authorized; 79,504,130 issued and 76,634,957 outstanding at June 30, 2016; 79,375,662 issued and 75,506,489 outstanding at December 31, 2015 |
1 |
1 | ||||
Additional paid-in capital |
428,618 |
423,499 | ||||
Retained earnings (deficit) |
(1,237,255) |
(925,824) | ||||
Treasury stock, at cost |
(24,167) |
(24,167) | ||||
Total shareholders' equity (deficit) |
(832,803) |
(526,491) | ||||
Total liabilities and shareholders' equity (deficit) |
$ |
998,354 |
$ |
1,208,022 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Statements of Cash Flows | |||||||
(Unaudited) | |||||||
Six Months Ended |
|||||||
June 30, |
|||||||
2016 |
2015 |
||||||
(In thousands) |
|||||||
Operating activities: |
|||||||
Net loss |
$ |
(311,431) |
$ |
(515,544) |
|||
Adjustments to reconcile net loss to net cash provided by (used in) operating activities: |
|||||||
Depreciation, depletion, amortization and accretion |
121,226 |
228,809 |
|||||
Ceiling test write-down of oil and natural gas properties |
221,151 |
513,162 |
|||||
Debt issuance costs write-off/amortization of debt items |
1,880 |
2,432 |
|||||
Share-based compensation |
5,121 |
5,708 |
|||||
Derivative loss |
2,449 |
1,078 |
|||||
Cash receipts on derivative settlements |
4,746 |
- |
|||||
Deferred income taxes |
19,285 |
(147,708) |
|||||
Asset retirement obligation settlements |
(25,156) |
(21,939) |
|||||
Changes in operating assets and liabilities |
(50,540) |
14,912 |
|||||
Net cash provided by (used in) operating activities |
(11,269) |
80,910 |
|||||
Investing activities: |
|||||||
Investment in oil and natural gas properties and equipment |
(17,712) |
(150,994) |
|||||
Changes in operating assets and liabilities associated with investing activities |
(34,122) |
(50,849) |
|||||
Proceeds from sales of assets |
1,500 |
- |
|||||
Purchases of furniture, fixtures and other |
(70) |
(709) |
|||||
Net cash used in investing activities |
(50,404) |
(202,552) |
|||||
Financing activities: |
|||||||
Borrowings of long-term debt - revolving bank credit facility |
340,000 |
194,000 |
|||||
Repayments of long-term debt - revolving bank credit facility |
(192,000) |
(381,000) |
|||||
Issuance of 9.00% Term Loan |
- |
297,000 |
|||||
Debt issuance costs |
- |
(6,407) |
|||||
Other |
83 |
54 |
|||||
Net cash provided by financing activities |
148,083 |
103,647 |
|||||
Increase (decrease) in cash and cash equivalents |
86,410 |
(17,995) |
|||||
Cash and cash equivalents, beginning of period |
85,414 |
23,666 |
|||||
Cash and cash equivalents, end of period |
$ |
171,824 |
$ |
5,671 |
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 Loss to Net Loss Excluding Special Items |
"Net Loss Excluding Special Items" does not include the unrealized commodity derivative loss, write-off of debt issuance and other non-operating costs, a contingent assessment provision, ceiling test write-down of oil and natural gas properties and associated tax effects. Net 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 |
Six Months Ended |
||||||||||||||
June 30, |
June 30, |
||||||||||||||
2016 |
2015 |
2016 |
2015 |
||||||||||||
(In thousands, except per share amounts) | |||||||||||||||
(Unaudited) | |||||||||||||||
Net loss |
$ |
(120,922) |
$ |
(260,449) |
$ |
(311,431) |
$ |
(515,544) |
|||||||
Unrealized commodity derivative loss |
5,583 |
1,078 |
7,195 |
1,078 |
|||||||||||
Write off of debt issuance and other non operating costs |
140 |
1,973 |
2,770 |
1,973 |
|||||||||||
Contingent assessment provision |
- |
1,000 |
- |
1,000 |
|||||||||||
Ceiling test write-down of oil and natural gas properties |
104,592 |
252,772 |
221,151 |
513,162 |
|||||||||||
Income tax adjustment for above items at current period tax rate |
(25,152) |
(37,239) |
(26,578) |
(115,338) |
|||||||||||
Net loss excluding special items |
$ |
(35,759) |
$ |
(40,865) |
$ |
(106,893) |
$ |
(113,669) |
|||||||
Basic and diluted loss per common share, excluding special items |
$ |
(0.47) |
$ |
(0.54) |
$ |
(1.40) |
$ |
(1.50) |
W&T OFFSHORE, INC. AND SUBSIDIARIES |
Non-GAAP Information |
Reconciliation of Net Loss to Adjusted EBITDA |
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative loss, write off of debt issuance and other non-operating costs and a contingent assessment provision. 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 (loss), 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 consolidated net loss to consolidated EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin. |
Three Months Ended |
Six Months Ended |
||||||||||||||
June 30, |
June 30, |
||||||||||||||
2016 |
2015 |
2016 |
2015 |
||||||||||||
(In thousands) | |||||||||||||||
(Unaudited) | |||||||||||||||
Net loss |
$ |
(120,922) |
$ |
(260,449) |
$ |
(311,431) |
$ |
(515,544) |
|||||||
Income tax benefit |
(35,722) |
(44,134) |
(40,604) |
(147,708) |
|||||||||||
Net interest expense |
29,647 |
24,091 |
57,056 |
45,252 |
|||||||||||
Depreciation, depletion, amortization and accretion |
57,493 |
103,342 |
121,226 |
228,809 |
|||||||||||
Ceiling test write-down of oil and natural gas properties |
104,592 |
252,772 |
221,151 |
513,162 |
|||||||||||
EBITDA |
35,088 |
75,622 |
47,398 |
123,971 |
|||||||||||
Adjustments: |
|||||||||||||||
Unrealized commodity derivative loss |
5,583 |
1,078 |
7,195 |
1,078 |
|||||||||||
Write off of debt issuance and other non operating costs |
140 |
1,973 |
2,770 |
1,973 |
|||||||||||
Contingent assessment provision |
- |
1,000 |
- |
1,000 |
|||||||||||
Adjusted EBITDA |
$ |
40,811 |
$ |
79,673 |
$ |
57,363 |
$ |
128,022 |
|||||||
Adjusted EBITDA Margin |
41% |
53% |
32% |
46% |
SOURCE W&T Offshore, Inc.
HOUSTON, July 25, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) (the "Company") today announced the commencement of an exchange offer and consent solicitation to eligible holders of its outstanding 8.500% Senior Notes due 2019 (the "Existing Notes") for up to (i) 62,100,000 shares of common stock, par value $0.00001 per share, of the Company (the "Shares"), (ii) $202.5 million aggregate principal amount of its new Senior Second Lien PIK Toggle Notes due 2020 (the "New Second Lien Notes") and (iii) $180.0 million aggregate principal amount of its new Senior PIK Toggle Notes due 2021 (the "New Unsecured Notes," together with the New Second Lien Notes, the "New Notes" and, together with the Shares, the "New Securities") pursuant to the terms of the offering memorandum and consent solicitation statement and the related letter of transmittal and consent (together, the "Offering Documents"). Concurrently with the exchange offer, the Company is soliciting consents from holders of the Existing Notes to a proposed amendment to the indenture governing the Existing Notes in order to permit the issuance of the New Second Lien Notes. The following table sets forth the consideration to be offered to eligible holders of the Existing Notes in the exchange offer:
Existing Notes to be Exchanged (CUSIP No. / ISIN) |
Aggregate Principal Amount Outstanding |
Total Exchange Consideration for each $1,000 Principal Amount of Existing Notes if Tendered Prior to or on the Early Participation Date |
Exchange Consideration for each $1,000 Principal Amount of Existing Notes if Tendered After the Early Participation Date |
8.500% Senior Notes due 2019 (92922P AC0 / US92922PAC05) |
$900,000,000 |
(i) 69 Shares; (ii) $225 principal amount of New Second Lien Notes; and (iii) $200 principal amount of New Unsecured Notes |
(i) 69 Shares; (ii) $200 principal amount of New Second Lien Notes; and (iii) $200 principal amount of New Unsecured Notes |
The total exchange consideration to be received by eligible holders of Existing Notes who validly tender and do not validly withdraw their Existing Notes prior to 5:00 p.m., New York City time, on August 8, 2016 (as it may be extended, the "Early Participation Date"), will include an early tender premium equal to $25 principal amount of New Second Lien Notes per $1,000 principal amount of Existing Notes accepted for exchange.
For Existing Notes validly tendered after the Early Participation Date and on or before the Expiration Date (as defined below), the eligible holders of Existing Notes accepted for exchange will be eligible to receive the exchange consideration set forth above, which does not include the early tender premium. Eligible holders of Existing Notes accepted for exchange will also receive a cash payment equal to the accrued and unpaid interest in respect of such Existing Notes from June 15, 2016 (the most recent interest payment date) to, but not including, the date the exchange offer is settled (the "Settlement Date"). Interest on the New Notes will accrue from the Settlement Date.
The exchange offer and consent solicitation will expire at 5:00 p.m., New York City time, on August 29, 2016, unless extended or earlier terminated by the Company (the "Expiration Date"). Tenders of Existing Notes and related consents in the exchange offer may be validly withdrawn at any time on or prior to 5:00 p.m., New York City time, on August 8, 2016 (the "Withdrawal Deadline"), but will thereafter be irrevocable, even if the Company otherwise extends the Early Participation Date or extends the exchange offer beyond the Expiration Date, except in certain limited circumstances where additional withdrawal rights are required by law. Tenders submitted in the exchange offer after the Withdrawal Deadline will be irrevocable, except in the limited circumstances where additional withdrawal rights are required by law. The act of tendering Existing Notes pursuant to the exchange offer will constitute a consent to the proposed amendment to the indenture governing the Existing Notes.
The exchange offer is conditioned on the satisfaction or waiver of certain additional conditions, as described in the Offering Documents, including, among other things, (i) the relevant shareholder approvals described in the Offering Documents related to the increase in the number of authorized shares of the Company's common stock and the issuance of the Shares and (ii) a minimum of 95%, or $855.0 million, of Existing Notes being tendered as of the Expiration Date. To the extent less than 90% in principal amount of the outstanding Existing Notes are validly tendered and accepted for exchange, the New Unsecured Notes will be secured by third-priority liens on substantially all of the Company's and its subsidiary guarantors' assets that secure the Company's revolving bank credit facility. The exchange offer and consent solicitation for the Existing Notes may be amended, extended or terminated.
The exchange offer and consent solicitation is only being made, and copies of the Offering Documents will only be made available, to holders of the Existing Notes who complete and submit an eligibility form confirming that they are (1) "qualified institutional buyers" within the meaning of Rule 144A under the Securities Act of 1933, as amended (the "Securities Act") or (2) not "U.S. persons" and are outside of the United States within the meaning of Regulation S under the Securities Act (such persons, "eligible holders"). Holders who desire to obtain and complete an eligibility form should contact the information agent, D.F. King & Co., Inc., at (877) 536-1561 (toll-free) or (212) 269-5550 (for banks and brokers), or via the following website: www.dfking.com/wti.
Eligible holders are urged to carefully read the Offering Documents before making any decision with respect to the exchange offer and consent solicitation. None of the Company, the sole dealer manager, the information agent or the exchange agent makes any recommendation as to whether eligible holders should tender or refrain from tendering their Existing Notes. Eligible holders must make their own decision as to whether to tender Existing Notes and, if so, the principal amount of Existing Notes to tender.
The New Securities offered by the Company have not been registered under the Securities Act, or any state securities laws and, unless so registered, may not be offered or sold in the United States except pursuant to an applicable exemption from the registration requirements of the Securities Act and applicable state securities laws. The exchange offer and consent solicitation is not being made to holders of Existing Notes in any jurisdiction in which the making or acceptance thereof would not be in compliance with the securities, blue sky or other laws of such jurisdiction. This press release is for informational purposes only and is not an offer to purchase, a solicitation of an offer to purchase or a solicitation of consents with respect to, any securities.
Evercore Group L.L.C. is acting as the sole dealer manager in the Exchange Offer.
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. As of March 31, 2016, the Company has working interests in approximately 54 fields in federal and state waters (50 producing and four fields capable of producing) and has under lease approximately 850,000 gross acres, including approximately 500,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 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 and Section 21E of the Securities Exchange Act of 1934, as amended. These forward-looking statements reflect the Company's current views with respect to future events, based on what it believes 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 the Company's 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, 2015 and subsequent Form 10-Q reports found at www.sec.gov or at the Company's website at www.wtoffshore.com under the Investor Relations section. Investors are urged to consider closely the disclosures and risk factors in these reports.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, July 12, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its second quarter 2016 financial and operational results after the market closes on Thursday, August 4. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Friday August 5 at 9:30 a.m. Eastern Time (8:30 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through August 12 by dialing 1-201-612-7415 and using the passcode 13639967. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 850,000 gross acres, including approximately 500,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. For more information on W&T Offshore, please visit our website at www.wtoffshore.com.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, May 4, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its first quarter 2016 operations and financial results, as well as its 2016 second quarter and full year production and expense guidance. Some of the key items and subsequent events include:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "With the continued weakness in commodity prices, we remained focused on prudently managing our cash balance and liquidity position, while minimizing our capital expenditures and judiciously managing our expenses.
"Our oil production remains strong as we benefit from good production rates at Big Bend, Dantzler, Medusa and our Ewing Bank 910 projects that were placed on line within the last year. With no material near-term lease expirations and most of our acreage held by production, we have no new wells currently planned for the remainder of 2016 and will continue to reduce expenses as we focus on returning operating margins to acceptable levels."
Production, Revenues and Price: For the first quarter of 2016, our oil production was 1.9 million barrels, up 0.6% over the first quarter of 2015. NGL production was 357,900 barrels, down 19.2% from the first quarter of 2015. Natural gas production was 10.1 billion cubic feet ("Bcf") for the first quarter of 2016, down 18.4% from the first quarter of 2015. Our combined total production was 3.9 million barrels of oil equivalent ("MMBoe") in the first quarter of 2016, down 10.3% from the first quarter of 2015. Oil production for the first quarter of 2016 was lower than anticipated as our largest oil producing field was offline for three weeks as a result of a scheduled maintenance project on a third-party pipeline that services the platform. However, oil production was higher in the first quarter of 2016 compared to the first quarter of 2015 due to increases in production from the development of certain deepwater fields within the last year, offset by the loss of production as a result of the sale of our Yellow Rose field in October 2015 and production deferrals, which occurred at multiple offshore locations. Deferrals, in addition to the one described above, were attributable to third-party pipeline outages, operational issues, and maintenance. We estimate production deferrals were 0.8 MMBoe during the first quarter of 2016 and 0.5 MMBoe during the first quarter of 2015.
Revenues for the first quarter of 2016 were $77.7 million compared to $127.9 million in the first quarter of 2015. The decrease in revenues was primarily due to the steep decline in commodity prices, combined with lower overall production. Our average realized crude oil sales price was down $16.31 per barrel, or 37.9%, between the two quarters. NGLs prices declined 17.0%, or $2.85 per barrel, as a result of the decline in crude oil prices, continued weak natural gas prices and a significant oversupply of both ethane and propane, which comprise the majority of NGLs on a component basis. Natural gas prices were lower by $1.00 per Mcf, or 33.2%, from the first quarter of 2015. During the first quarter of 2016, our average realized sales price for oil was $26.73 per barrel, $13.96 per barrel for NGLs and $2.01 per Mcf for natural gas. On a combined basis, we sold 43,317 Boe per day at an average realized sales price of $19.33 per Boe compared to 48,837 Boe per day sold at an average realized sales price of $28.70 per Boe in the first quarter of 2015.
WTI crude oil prices averaged $33.35 per barrel for the first quarter of 2016 compared to our average realized crude oil price of $26.73 per barrel. WTI is frequently used to value domestically produced crude oil, and the majority of our oil production is priced using the spot price for WTI as a base price, then adjusted for the type and quality of crude oil and other factors. Just like crude oil prices, the differentials for our offshore crude oil have also experienced significant volatility. For example, the monthly average differentials of WTI versus LLS, HLS and Poseidon for the first quarter of 2016 were a positive $1.60 and $0.80, and a negative $3.71 per barrel, respectively. The majority of our crude oil is priced similar to Poseidon and, therefore, is experiencing negative differentials. In addition, a few of our crude oil fields have a negative quality bank adjustment due to crude oil quality and production from two of our crude oil fields is transported via barge, which is more expensive than pipeline transportation.
Cash Flow from Operating Activities and Adjusted EBITDA: EBITDA, Adjusted EBITDA, and Adjusted EBITDA margin are non-GAAP measures and are defined in the "Non-GAAP Financial Measures" section at the end of this news release.
Cash flows from operating activities, before changes in working capital and ARO settlements, were a negative $9.3 million for the first three months of 2016, compared to $30.2 million generated over the same period in 2015. Cash flows declined as revenues were $50.2 million lower in the 2016 period compared to the 2015 period. Payments to settle asset retirement obligations totaled $3.2 million in the first three months of 2016.
Adjusted EBITDA for the first quarter of 2016 was $16.6 million, down from $48.3 million generated over the same period in 2015. Our Adjusted EBITDA margin was 21% in the 2016 period compared to 38% in the 2015 period.
Net cash provided by operating activities for the first three months of 2016 was $29.7 million compared to $52.9 million for the same period in 2015.
Liquidity: At March 31, 2016, we had a cash balance of $370.6 million and no amount of undrawn capacity available under our revolving bank credit facility.
During February of 2016, we borrowed $340 million under our Credit Agreement. On March 23, 2016, the borrowing base under our Credit Agreement was reduced as part of the spring redetermination from $350 million to $150 million. We are required to repay the amount of borrowings and letters of credit in excess of the redetermined borrowing base in three installments over 90 days. We repaid $52 million on March 31, 2016 and $12 million on May 2, 2016. We are required to repay $64 million on May 31, 2016 and $64 million on June 30, 2016, in addition to interest payments on our long-term debt.
In February and March, 2016, the Company received several orders from the BOEM demanding that the Company provide additional supplemental bonding on certain Federal offshore oil and gas leases, rights of way and rights of use and easement owned and/or operated by the Company. One order was rescinded and re-issued and another one was rescinded. The outstanding orders total $260.8 million. We have filed appeals with the Interior Board of Land Appeals regarding three of the BOEM orders - specifically the February order that required W&T to post a total of $159.8 million in supplemental bonding and two March orders requiring $68 million in supplemental bonding. We have had numerous discussions with the BOEM and its sister agency, the BSEE, since receiving the orders. The objective of the Company remains to reach a mutual agreement on the financial assurance requirements.
The issuance of any additional surety bonds to satisfy the BOEM orders or any future BOEM orders may require the posting of cash collateral, which may be significant, and the creation of escrow accounts. We continue to have discussions with BOEM regarding these matters.
Lease Operating Expenses: LOE, which includes base lease operating expenses, insurance premiums, workovers, and maintenance expenses on our facilities decreased $8.9 million, or 16.6%, to $44.5 million in the first quarter of 2016 compared to the first quarter of 2015. On a per Boe basis, lease operating expenses decreased to $11.28 per Boe in the first quarter of 2016, a 7.0% reduction compared to $12.13 per Boe in the first quarter of 2015. On a component basis, base lease operating expenses decreased $5.2 million, workover expense decreased $1.9 million, and insurance premiums decreased $1.6 million. Base lease operating expenses decreased primarily due to lower costs from service providers ($9.2 million) and the sale of the Yellow Rose field in October 2015 ($5.9 million), partially offset by increases in expenses related to our new deepwater fields at Dantzler and Big Bend ($5.6 million), lower production handling fees (cost offsets) at our Mississippi Canyon 243 field (Matterhorn) ($2.9 million) and costs associated with delinquent joint venture partners ($1.4 million). The decrease in workover costs was primarily due to the sale of the Yellow Rose field and reduced activities offshore.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for ARO, decreased to $16.17 per Boe for the first quarter of 2016 from $28.55 per Boe for the first quarter of 2015. On a nominal basis, DD&A decreased to $63.7 million for the first quarter of 2016 from $125.5 million for the first quarter of 2015 due to a decrease in the DD&A rate per Boe and lower production volumes. The DD&A rate per Boe decreased primarily due to the ceiling test write-downs recorded in 2015, the proceeds from the sale of the Yellow Rose field and the decrease in associated future development costs. Other factors affecting the DD&A rate are lower net proved reserves, the general reduction in the costs of goods and services and lower capital expenditures in relation to DD&A expense, which lowered the full-cost pool subject to DD&A.
Ceiling test write-down of oil and natural gas properties: For the first quarter of 2016, we recorded a non-cash ceiling test write-down of $116.6 million as the book value of our oil and natural gas properties exceeded the ceiling test limitation. The write-down resulted from a significant reduction in the market value of all three commodities we sell. For the first quarter of 2015, the ceiling test write-down was $260.4 million.
General and Administrative Expenses ("G&A"): G&A decreased $4.3 million, or 20.8% to $16.4 million for the first quarter of 2016 compared to the first quarter of 2015. The decrease was primarily due to decreases in headcount, benefits, contractor expenses and costs related to surety bonds (due to timing), partially offset by higher legal and professional services costs. G&A on a per BOE basis was $4.17 Boe for the first quarter of 2016 compared to $4.72 per Boe for the first quarter of 2015.
Derivatives: For the first quarter of 2016, we recorded a $2.5 million derivative gain for derivative contracts for crude oil and natural gas. For the first quarter of 2015, there were no derivative contracts in place. The Company has hedges in place covering about one-third of our estimated 2016 production. A report providing our commodity derivative positions is posted to our website.
Income Taxes: Our income tax benefit for the first quarter of 2016 was $4.9 million, down significantly from $103.6 million in the first quarter of 2015. The change is attributable primarily to changes in the pre-tax loss and changes in the valuation allowance recorded for the respective periods. Our annualized effective tax rate for the first quarter of 2016 was 2.5% and differs from the federal statutory rate of 35% primarily due to recording and adjusting a valuation allowance related to federal and state deferred tax assets. During the three months ended March 31, 2016 and 2015, we recorded a valuation allowance of $60.0 million and $22.5 million, respectively, related to federal and state deferred tax assets. Deferred tax assets are recorded related to net operating losses and temporary differences between the book and tax basis of assets and liabilities expected to produce tax deductions in future periods. The realization of these assets depends on recognition of sufficient future taxable income in specific tax jurisdictions in which those temporary differences or net operating losses are deductible. In assessing the need for a valuation allowance on our deferred tax assets, we consider whether it is more likely than not that some portion or all of them will not be realized.
Net Income (Loss) & Earnings (Loss) Per Share: We reported a net loss for the first quarter of 2016 of ($190.5) million, or ($2.49) per common share, compared to net loss of ($255.1) million, or ($3.36) per common share, during the same period in 2015. Excluding special items (including the ceiling test write-down of oil and natural gas properties, write off of debt issuance and other non-operating costs and an unrealized commodity derivative loss, net of applicable federal income tax at the effective tax rate for the periods presented), our net loss for the first quarter of 2016 was ($72.7) million, or ($0.95) per common share, compared to first quarter 2015 net loss of ($70.0) million, or ($0.92) per common share. Operating results for the first quarter of 2016, excluding special items, were down primarily due to a $50.2 million decrease in revenues primarily driven by a 32.6% decline in our realized prices and a significantly lower federal income tax benefit, partially offset by an $8.9 million decrease in LOE, a $61.7 million decrease in DD&A and a $4.3 million decrease in G&A.
See the "Reconciliation of Net Loss to Net Loss 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.
2016 Capital Expenditures Update: Our capital expenditures on an accrual basis for the first quarter of 2016 were $12.9 million ($33.6 million on a cash basis) compared to $82.8 million ($135.2 million on a cash basis) for first quarter of 2015. In 2016, the substantial majority of our capital expenditures were directed at completion activities of the Ewing Bank 954 A-8 well in the amount of $11.6 million. The remainder of the expenditures was associated with other development activities, seismic and capitalized interest.
Our capital expenditure budget for 2016 remains set at $15 million, excluding expenses associated with plug and abandonment activities which is currently estimated to total $76 million and is expected to be funded with cash on hand and cash flow from operating activities.
OPERATIONS UPDATE
Offshore Gulf of Mexico:
Ewing Bank 954 A-8 (part of the Ewing Bank 910 field) (50% WI, deepwater)
In the first quarter, the Company completed in two separate zones the Ewing Bank 954 A-8 well, which was drilled from the EW 910 platform. This is the second well in a two-well exploration program drilled from the EW 910 platform and followed the earlier discovery at the ST 320 A-5 well in May 2015. The EW 954 A-8 well reached total depth in December and penetrated a total of 150 feet of measured depth hydrocarbon pay contained in two sands. The well has achieved a gross initial production rate from the lower sand completion of approximately 3,500 Boe per day. We also have pre-completed a second zone in the A-8 well, which was actually the primary and larger original target zone and plan to place this second completion on production later as the lower completion depletes.
Second Quarter and Full Year 2016 Outlook
Our guidance for the second quarter and full year 2016 is provided in the table below and represents the Company's best estimate of the range of likely future results. Guidance could be affected by the factors described below in "Forward-Looking Statements."
Second Quarter |
Full Year |
||||
Production |
2016 |
2016 |
|||
Oil and NGLs (MMBbls) |
2.1 - 2.3 |
8.5 - 9.3 |
|||
Natural gas (Bcf) |
9.9 - 10.9 |
37.9 - 41.9 |
|||
Total (Bcf) |
22.5 - 24.9 |
88.8 - 98.2 |
|||
Total (MMBoe) |
3.7 - 4.2 |
14.8 - 16.4 |
|||
Operating Expenses |
Second Quarter |
Prior Full Year |
|||
($ in million) |
2016 |
2016 |
|||
Lease operating expenses |
$44.7 - $49.3 |
$166 - $184 |
|||
Gathering, transportation & production taxes |
$5 - $6 |
$22 - $24 |
|||
General and administrative |
$16.1 - $17.8 |
$61 - $68 |
|||
Income tax rate (100% deferred) |
6.7% |
4.4% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Thursday, May 5, 2016, at 9:30 a.m. Eastern 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 approximately two hours after the end of the call until May 12, 2016 and may be accessed by calling 201-612-7415 and using the passcode 13635554.
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 850,000 gross acres, including approximately 500,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. For more information on W&T Offshore, please visit our 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 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 W&T Offshore's Annual Report on Form 10-K for the year ended December 31, 2015 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.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||
Condensed Consolidated Statements of Income (Loss) | ||||||||
(Unaudited) | ||||||||
Three Months Ended |
||||||||
March 31, |
||||||||
2016 |
2015 |
|||||||
(In thousands, except per share data) | ||||||||
Revenues |
$ |
77,715 |
$ |
127,907 |
||||
Operating costs and expenses: |
||||||||
Lease operating expenses |
44,469 |
53,331 |
||||||
Gathering, transportation costs and production taxes |
5,618 |
5,461 |
||||||
Depreciation, depletion, amortization and accretion |
63,733 |
125,467 |
||||||
Ceiling test write-down of oil and natural gas properties |
116,559 |
260,390 |
||||||
General and administrative expenses |
16,443 |
20,766 |
||||||
Derivative gain |
(2,493) |
- |
||||||
Total costs and expenses |
244,329 |
465,415 |
||||||
Operating loss |
(166,614) |
(337,508) |
||||||
Interest expense: |
||||||||
Incurred |
27,814 |
22,946 |
||||||
Capitalized |
(343) |
(1,783) |
||||||
Other (income) expense, net |
1,306 |
(2) |
||||||
Loss before income tax benefit |
(195,391) |
(358,669) |
||||||
Income tax benefit |
(4,882) |
(103,574) |
||||||
Net loss |
$ |
(190,509) |
$ |
(255,095) |
||||
Basic and diluted loss per common share |
$ |
(2.49) |
$ |
(3.36) |
||||
Weighted average common shares outstanding |
76,428 |
75,857 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Three Months Ended |
||||||||||||
March 31, |
Variance | |||||||||||
2016 |
2015 |
Variance |
Percentage (2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
1,906 |
1,894 |
12 |
0.6% | ||||||||
NGL (MBbls) |
358 |
443 |
(85) |
-19.2% | ||||||||
Oil and NGLs (MBbls) |
2,263 |
2,337 |
(74) |
-3.2% | ||||||||
Natural gas (MMcf) |
10,071 |
12,349 |
(2,278) |
-18.4% | ||||||||
Total oil and natural gas (MBoe) (1) |
3,942 |
4,395 |
(453) |
-10.3% | ||||||||
Total oil and natural gas (MMcfe) (1) |
23,651 |
26,372 |
(2,721) |
-10.3% | ||||||||
Average daily equivalent sales (MBoe/d) |
43.3 |
48.8 |
(5.5) |
-11.3% | ||||||||
Average daily equivalent sales (MMcfe/d) |
259.9 |
293.0 |
(33.1) |
-11.3% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
26.73 |
$ |
43.04 |
$ |
(16.31) |
-37.9% | |||||
NGLs ($/Bbl) |
13.96 |
16.81 |
(2.85) |
-17.0% | ||||||||
Oil and NGLs ($/Bbl) |
24.71 |
38.07 |
(13.36) |
-35.1% | ||||||||
Natural gas ($/Mcf) |
2.01 |
3.01 |
(1.00) |
-33.2% | ||||||||
Barrel of oil equivalent ($/Boe) |
19.33 |
28.70 |
(9.37) |
-32.6% | ||||||||
Natural gas equivalent ($/Mcfe) |
3.22 |
4.78 |
(1.56) |
-32.6% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
11.28 |
$ |
12.13 |
$ |
(0.85) |
-7.0% | |||||
Gathering and transportation costs and production taxes |
1.43 |
1.24 |
0.19 |
15.3% | ||||||||
Depreciation, depletion, amortization and accretion |
16.17 |
28.55 |
(12.38) |
-43.4% | ||||||||
General and administrative expenses |
4.17 |
4.72 |
(0.55) |
-11.7% | ||||||||
Adjusted EBITDA |
4.20 |
11.00 |
(6.80) |
-61.8% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.88 |
$ |
2.02 |
$ |
(0.14) |
-6.9% | |||||
Gathering and transportation costs and production taxes |
0.24 |
0.21 |
0.03 |
14.3% | ||||||||
Depreciation, depletion, amortization and accretion |
2.69 |
4.76 |
(2.07) |
-43.5% | ||||||||
General and administrative expenses |
0.70 |
0.79 |
(0.09) |
-11.4% | ||||||||
Adjusted EBITDA |
0.70 |
1.83 |
(1.13) |
-61.7% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Balance Sheets | |||||||
(Unaudited) | |||||||
March 31, |
December 31, | ||||||
2016 |
2015 | ||||||
(In thousands, except | |||||||
share data) | |||||||
Assets |
|||||||
Current assets: |
|||||||
Cash and cash equivalents |
$ |
370,623 |
$ |
85,414 | |||
Receivables: |
|||||||
Oil and natural gas sales |
27,903 |
35,005 | |||||
Joint interest and other |
17,006 |
22,012 | |||||
Total receivables |
44,909 |
57,017 | |||||
Prepaid expenses and other assets |
23,035 |
26,879 | |||||
Total current assets |
438,567 |
169,310 | |||||
Property and equipment – at cost: |
|||||||
Oil and natural gas properties and equipment (full cost method, of which $5,165 at March 31, 2016 and $18,595 at December 31, 2015 were excluded from amortization) |
7,895,402 |
7,902,494 | |||||
Furniture, fixtures and other |
20,802 |
20,802 | |||||
Total property and equipment |
7,916,204 |
7,923,296 | |||||
Less accumulated depreciation, depletion and amortization |
7,108,925 |
6,933,247 | |||||
Net property and equipment |
807,279 |
990,049 | |||||
Deferred income taxes |
32,553 |
27,595 | |||||
Restricted deposits for asset retirement obligations |
16,171 |
15,606 | |||||
Other assets |
4,225 |
5,462 | |||||
Total assets |
$ |
1,298,795 |
$ |
1,208,022 | |||
Liabilities and Shareholders' Equity (Deficit) |
|||||||
Current liabilities: |
|||||||
Accounts payable |
$ |
92,045 |
$ |
109,797 | |||
Undistributed oil and natural gas proceeds |
20,654 |
21,439 | |||||
Asset retirement obligations |
83,778 |
84,335 | |||||
Accrued liabilities |
39,486 |
11,922 | |||||
Current portion of long-term debt |
138,999 |
- | |||||
Total current liabilities |
374,962 |
227,493 | |||||
Long-term debt, less current maturities |
1,345,954 |
1,196,855 | |||||
Asset retirement obligations, less current portion |
275,986 |
293,987 | |||||
Other liabilities |
16,357 |
16,178 | |||||
Commitments and contingencies |
- |
- | |||||
Shareholders' equity (deficit): |
|||||||
Common stock, $0.00001 par value; 118,330,000 shares authorized; 79,375,662 issued and 75,506,489 outstanding at March 31, 2016 and December 31, 2015 |
1 |
1 | |||||
Additional paid-in capital |
426,035 |
423,499 | |||||
Retained earnings (deficit) |
(1,116,333) |
(925,824) | |||||
Treasury stock, at cost; 2,869,173 shares at March 31, 2016 and December 31, 2015 |
(24,167) |
(24,167) | |||||
Total shareholders' equity (deficit) |
(714,464) |
(526,491) | |||||
Total liabilities and shareholders' equity (deficit) |
$ |
1,298,795 |
$ |
1,208,022 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||
Condensed Consolidated Statements of Cash Flows | ||||||||
(Unaudited) | ||||||||
Three Months Ended |
||||||||
March 31, |
||||||||
2016 |
2015 |
|||||||
(In thousands) |
||||||||
Operating activities: |
||||||||
Net loss |
$ |
(190,509) |
$ |
(255,095) |
||||
Adjustments to reconcile net loss to net cash provided by operating activities: |
||||||||
Depreciation, depletion, amortization and accretion |
63,733 |
125,467 |
||||||
Ceiling test write-down of oil and natural gas properties |
116,559 |
260,390 |
||||||
Debt issuance costs write-down/amortization of debt items |
1,684 |
156 |
||||||
Share-based compensation |
2,536 |
2,816 |
||||||
Derivative gain |
(2,493) |
- |
||||||
Cash payments on derivative settlements |
4,105 |
- |
||||||
Deferred income taxes |
(4,882) |
(103,574) |
||||||
Asset retirement obligation settlements |
(3,180) |
(19,554) |
||||||
Changes in operating assets and liabilities |
42,156 |
42,312 |
||||||
Net cash provided by operating activities |
29,709 |
52,918 |
||||||
Investing activities: |
||||||||
Investment in oil and natural gas properties and equipment |
(12,903) |
(82,765) |
||||||
Changes in operating assets and liabilities associated with investing activities |
(20,680) |
(52,176) |
||||||
Proceeds from sales of assets |
1,000 |
- |
||||||
Purchases of furniture, fixtures and other |
- |
(226) |
||||||
Net cash used in investing activities |
(32,583) |
(135,167) |
||||||
Financing activities: |
||||||||
Borrowings of long-term debt - revolving bank credit facility |
340,000 |
82,000 |
||||||
Repayments of long-term debt - revolving bank credit facility |
(52,000) |
(15,000) |
||||||
Other |
83 |
(50) |
||||||
Net cash provided by financing activities |
288,083 |
66,950 |
||||||
Increase (decrease) in cash and cash equivalents |
285,209 |
(15,299) |
||||||
Cash and cash equivalents, beginning of period |
85,414 |
23,666 |
||||||
Cash and cash equivalents, end of period |
$ |
370,623 |
$ |
8,367 |
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 Loss to Net Loss Excluding Special Items |
"Net Loss Excluding Special Items" does not include the unrealized commodity derivative loss, write-off of debt issuance and other non-operating costs, ceiling test write-down of oil and natural gas properties and associated tax effects. Net 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 | |||||||||
March 31, | |||||||||
2016 |
2015 | ||||||||
(In thousands, except per share amounts) | |||||||||
(Unaudited) | |||||||||
Net loss |
$ |
(190,509) |
$ |
(255,095) | |||||
Unrealized commodity derivative loss |
1,612 |
- | |||||||
Write off of debt issuance and other non operating costs |
2,630 |
- | |||||||
Ceiling test write-down of oil and natural gas properties |
116,559 |
260,390 | |||||||
Income tax adjustment for above items at current period tax rate |
(3,020) |
(75,253) | |||||||
Net loss excluding special items |
$ |
(72,728) |
$ |
(69,958) | |||||
Basic and diluted loss per common share, excluding special items |
$ |
(0.95) |
$ |
(0.92) |
W&T OFFSHORE, INC. AND SUBSIDIARIES |
Non-GAAP Information |
Reconciliation of Net Loss to Adjusted EBITDA |
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the unrealized commodity derivative loss, write off of debt issuance and other non-operating costs. 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 (loss), 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 consolidated net loss to consolidated EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin. |
Three Months Ended | |||||||||
March 31, | |||||||||
2016 |
2015 | ||||||||
(In thousands) | |||||||||
(Unaudited) | |||||||||
Net loss |
$ |
(190,509) |
$ |
(255,095) | |||||
Income tax benefit |
(4,882) |
(103,574) | |||||||
Net interest expense |
27,409 |
21,161 | |||||||
Depreciation, depletion, amortization and accretion |
63,733 |
125,467 | |||||||
Ceiling test write-down of oil and natural gas properties |
116,559 |
260,390 | |||||||
EBITDA |
12,310 |
48,349 | |||||||
Adjustments: |
|||||||||
Unrealized commodity derivative loss |
1,612 |
- | |||||||
Write off of debt issuance and other non operating costs |
2,630 |
- | |||||||
Adjusted EBITDA |
$ |
16,552 |
$ |
48,349 | |||||
Adjusted EBITDA Margin |
21% |
38% |
SOURCE W&T Offshore, Inc.
HOUSTON, April 15, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its first quarter 2016 financial and operational results after the market closes on Wednesday, May 4. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Thursday, May 5 at 9:30 a.m. Eastern Time (8:30 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through May 12 by dialing 1-201-612-7415 and using the passcode 13635554. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 900,000 gross acres, including approximately 550,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. For more information on W&T Offshore, please visit our website at www.wtoffshore.com.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, March 24, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that its borrowing base under its revolving bank credit facility has been reduced to $150 million from $350 million, effective March 23, 2016. In February 2016, the Company drew $340 million on its revolving bank credit facility and now has borrowings of $191 million in excess of the redetermined borrowing base. Excess borrowings are required to be repaid in three equal monthly installments. W&T currently has a cash balance of $431 million.
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 offshore fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 900,000 gross acres offshore, including approximately 550,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate offshore. For more information on W&T Offshore, please visit our website at www.wtoffshore.com.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
HOUSTON, March 8, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) today reported its fourth quarter 2015 operations and financial results, as well as its 2016 full year production and expense guidance. Some of the key items and subsequent events include:
Tracy W. Krohn, W&T Offshore's Chairman and Chief Executive Officer, stated, "While 2015 was another outstanding year for our operations in the Gulf of Mexico, we continue to further prepare the Company to weather this period of extreme low prices. Even with our drastically reduced 2015 capital plan, we brought on-line three substantial 2015 deepwater exploration discoveries, achieved 100% exploration success for the third year in a row, and commenced production of our earlier discoveries at Big Bend and Dantzler.
"We are pleased that the production at our Rio Grande Loop project from the Big Bend and Dantzler wells has remained strong and is down only slightly from the peak rate achieved in December. We are also pleased with the high quality pay sands found in the Ewing Banks 954 A-8 well, which reached total depth in December and came on line last week. We have already seen gross production rates from this well of almost 3,500 Boe per day and the well is still cleaning up, and believe the field offers additional opportunities for future drilling. We expect our deepwater projects completed in 2015, combined with new production from our EW 954 A-8 well will help with 2016 production levels. However, unplanned downtime, pipeline maintenance, and well performance are factors leading to lower estimated production in 2016 from 2015.
"Our year-over-year 2015 proved reserves still only reflect a modest impact from our Big Bend and Dantzler discoveries and would have reflected more of our 2015 drilling successes had it not been for the impact of significantly reduced commodity prices. Regardless, we would have replaced our 2015 production with discoveries, extensions and revisions of proved reserves, had it not been for the steep decline in commodity prices.
"In 2015, the average realized price we received per Boe dropped 45% compared to the prior year, and in the first few months of 2016 it has dropped even further. Under the current market conditions, we intend to protect our liquidity, our balance sheet and our cash position, as well as continue to aggressively cut costs and reduce expenses. Our lease operating expenses decreased 35% in the fourth quarter and 27% for the full year while our general and administrative expenses were down 29% in the fourth quarter and down 16% for the year in 2015.
"Also in response to declining product pricing, we slashed our capital expenditures for drilling and development while preserving our inventory of drilling opportunities. With the sale of our Yellow Rose field in West Texas in October, we substantially boosted our liquidity and further increased our cash balance in February 2016 with a full draw-down of our revolving credit facility by $340 million. Our cash position subsequent to the draw was $447 million which we intend to manage judiciously in the face of an expected reduction in our borrowing base and demands for additional coverage and collateral for our supplemental P&A bonding program. We have no long-term drilling rig contracts or drilling obligations of any significance, no material near-term lease expirations as most of our acreage is held by production, and we have no debt obligations that mature in the near term," concluded Mr. Krohn.
Production, Revenues and Price: For the fourth quarter of 2015, our oil production was 1.975 million barrels, up 7.9% over the fourth quarter of 2014. NGL production was 363,450 barrels, down 36.0% from the fourth quarter of 2014. Natural gas production was 10.7 Bcf for the fourth quarter of 2015, down 18.6% from the fourth quarter of 2014. Our combined total production was 4.1 MMBoe in the fourth quarter of 2015, down 10.2% from the fourth quarter of 2014.
Revenues for the fourth quarter of 2015 were $104.1 million compared to $196.7 million in the fourth quarter of 2014. Revenues decreased due to the steep decline in commodity prices. Crude oil prices were down $33.73 per barrel, or 47.7%, between the two quarters. NGLs prices declined 40.1%, or $10.81 per barrel, as a result of the decline in crude oil prices, continued weak natural gas prices and a significant oversupply of both ethane and propane, which comprise the majority of NGLs on a component basis. Natural gas prices were lower by $1.62 per Mcf, or 42.5%, from the fourth quarter of 2014. During the fourth quarter of 2015, our average realized sales price for oil was $36.99 per barrel, $16.16 per barrel for NGLs and $2.19 per Mcf for natural gas. On a combined basis, we sold 44,790 Boe per day at an average realized sales price of $24.84 per Boe compared to 49,862 Boe per day sold at an average realized sales price of $42.46 per Boe in the fourth quarter of 2014.
Cash Flow from Operating Activities and Adjusted EBITDA: EBITDA, Adjusted EBITDA, and Adjusted EBITDA margin are non-GAAP measures and are defined in the "Non-GAAP Financial Measures" section at the end of this news release.
Cash flows from operating activities, before changes in working capital and ARO settlements, were $140.3 million for the year ended December 31, 2015, compared to $500.8 million generated over the same period in 2014. Cash flows declined as revenues were $441.4 million lower in the 2015 period compared to the 2014 period. Payments to settle asset retirement obligations totaled $32.6 million in 2015.
Adjusted EBITDA for the year ended December 31, 2015 was $225.0 million, down from $569.2 million generated over the same period in 2014. Our Adjusted EBITDA margin was 44% in the 2015 period compared to 60% in the 2014 period.
Net cash provided by operating activities for the full year of 2015 was $132.6 million compared to $474.0 million for the same period in 2014.
Liquidity: At December 31, 2015, we had a cash balance of $85.4 million and $349.1 million of undrawn capacity available under our revolving bank credit facility, which had a borrowing base of $350.0 million. On October 15, 2015, we closed on the sale of our interest in our Yellow Rose field for approximately $372.9 million and the assumption by the buyer of the ARO associated with the field. Proceeds from the sale were used to pay off all borrowings outstanding under our revolving bank credit facility (which were subsequently reborrowed) with the remaining balance of approximately $100 million added to available cash balances.
In February 2016, we borrowed substantially all of our available borrowings of $340 million remaining under the Company's revolving bank credit facility, to be used for general corporate purposes. Including these funds, the Company's cash position subsequent to the draw was $447 million. Our next scheduled borrowing base redetermination under our revolving bank credit facility will likely occur before the end of March 2016. To the extent our outstanding borrowings exceed the amount of the redetermined borrowing base, we will have to repay such excess borrowings in three equal monthly installments.
In February and March, 2016, the Company received several letters from the U.S. Department of the Interior's Bureau of Ocean Energy Management ("BOEM") ordering the Company to provide additional supplemental bonding on or before March 29, 2016, in the aggregate amount of $260.8 million to cover its obligations under certain Federal offshore oil and gas leases operated by the Company. The issuance of any additional surety bonds to satisfy the BOEM order or any future orders may require the posting of cash collateral, which could be substantial. We plan to continue our discussions with BOEM regarding satisfying their requests for additional financial assurances.
Lease Operating Expenses: LOE, which includes base lease operating expenses, insurance premiums, workovers, and maintenance expenses on our facilities decreased $26.4 million, or 34.9%, to $49.3 million in the fourth quarter of 2015 compared to the fourth quarter of 2014. On a per Boe basis, lease operating expenses decreased to $11.96 per Boe in the fourth quarter of 2015, a 27.5% reduction compared to $16.49 per Boe in the fourth quarter of 2014. On a component basis, base LOE (which includes insurance) decreased $7.2 million primarily due to lower costs from service providers, reduced onshore downhole well work activities and reduced insurance costs. Workover costs decreased $17.5 million due to reduced workovers performed at our Yellow Rose field before it was sold in October 2015 and two rig workovers that occurred in the 2014 period that did not reoccur in the 2015 period. Facilities maintenance expenses decreased $1.7 million due to reduced activity at multiple offshore locations and general cost reductions similar to those discussed above for base LOE.
Depreciation, depletion, amortization and accretion ("DD&A"): DD&A, including accretion for ARO, decreased to $16.49 per Boe for the fourth quarter of 2015 from $28.53 per Boe for the fourth quarter of 2014. On a nominal basis, DD&A decreased to $67.9 million for the fourth quarter of 2015 from $130.9 million for the fourth quarter of 2014 due to a decrease in the DD&A rate per Boe. The DD&A rate per Boe decreased primarily due to the ceiling test write-downs recorded in 2015, the proceeds from the sale of the Yellow Rose field and lower capital expenditures in relation to DD&A expense, which lowered the full-cost pool subject to DD&A. Additional factors affecting the DD&A rate were the sale of the Yellow Rose field in October 2015 and the resultant decrease in future development costs, lower net proved reserves and the general reduction in the costs of goods and services.
Ceiling test write-down of oil and natural gas properties: For the fourth quarter of 2015, we recorded a non-cash ceiling test write-down of $32.4 million as the book value of our oil and natural gas properties exceeded the ceiling test limitation. The write-down resulted from a significant reduction in the market value of all three commodities we sell. Ceiling test write-downs during 2015 totaled $987.2 million. No ceiling test write-down was recorded during 2014.
General and Administrative Expenses ("G&A"): G&A decreased $6.7 million, or 29.3% to $16.1 million for the fourth quarter of 2015 compared to the fourth quarter of 2014. The decrease was primarily due to lower incentive compensation and bonus costs, a general reduction in contractor usage, and a decrease in professional fees, partially offset by lower billings to joint venture partners and higher surety bond premiums. G&A on a per Boe basis was $3.90 per Boe for the fourth quarter of 2015 compared to $4.95 per Boe for the fourth quarter of 2014.
Derivatives: For the fourth quarter of 2015, we recorded a $5.2 million derivative gain for derivative contracts for crude oil and natural gas. For the fourth quarter of 2014, derivative gains were $10.8 million related to derivative contracts for crude oil. No new contracts were entered into during the fourth quarter of either year. The Company has hedges in place covering approximately 35% of estimated 2016 production. A report providing our commodity derivative positions is posted to our website.
Income Taxes: Our income tax benefits for the three months ended and for the full year ended December 31, 2015 were $36.8 million and $203.0 million, respectively. These income tax benefits were partially attributable to recording ceiling test write-downs of $32.4 million and $987.2 million in the fourth quarter and full year of 2015, respectively, and the significant decline in commodity prices. Our effective tax rate for the fourth quarter of 2015 was 41.6%, and our effective tax rate for the twelve months ended December 31, 2015 was 16.3%. Both of these percentages differ from the federal statutory rate of 35.0% primarily due to recording a valuation allowance against a majority of our deferred tax assets. Income tax benefits were $17.3 million and $4.5 million for the three months ended and for the year ended December 31, 2014, respectively. Our effective tax rates for the three months and full year ended December 31, 2014 were 34.1% and 27.7%, respectively.
Our valuation allowance at December 31, 2015 is $232.9 million and relates to federal deferred tax assets. Deferred tax assets are related to net operating losses and temporary differences between the book and tax basis of assets and liabilities expected to produce tax deductions in future periods. The realization of these assets depends on recognition of sufficient taxable income in the future. In assessing the need for a valuation allowance on our deferred tax assets, we consider whether it is more likely than not that some portion or all of them will not be realized in the future. We have $418.4 million of federal net operating loss carryforwards and carrybacks (tax basis) available to offset future and prior federal taxable income.
Net Income (Loss) & Earnings (Loss) Per Share: We reported a net loss for the fourth quarter of 2015 of ($51.6) million, or ($0.68) per common share, compared to net loss of ($33.4) million, or ($0.44) per common share, during the same period in 2014. Excluding special items (including the ceiling test write-down of oil and natural gas properties and derivative gains in 2014 and 2015, net of applicable federal income tax at the effective tax rate for the periods presented), our net loss for the fourth quarter of 2015 was ($33.4) million, or ($0.44) per common share, compared to fourth quarter 2014 net loss of ($40.5) million, or ($0.54) per common share. Operating results for the fourth quarter of 2015, excluding special items, were down primarily due to a $92.6 million decrease in revenues driven by a 41.5% decline in our realized prices, partially offset by a $26.4 million decrease in LOE and a $63.0 million decrease in DD&A and a $6.7 million decrease in G&A.
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 Financial Information" at the end of this news release for a description of the special items.
2015 Capital Expenditures Update: Our capital expenditures on an accrual basis for the year ended December 31, 2015 were $231.4 million compared to $630.0 million for the same period in 2014. In 2015, capital expenditures for oil and gas properties consisted of $53.1 million for exploration activities, $173.1 million for development activities and $4.0 million for acquisition activities. Over 95% of our capital expenditures was dedicated to offshore, primarily the deepwater, with only $11.2 million dedicated to onshore. For the year ended December 31, 2015, we completed five deepwater wells with two wells at Dantzler, two wells at Medusa and one well at the Ewing Bank 910 field. For the same period of 2015 we completed five wells onshore.
2016 Capital Budget
The Company's capital expenditure budget for 2016 is currently set at $15 million, which excludes approximately $84 million for plug and abandonment activities and is expected to be funded with cash on hand and cash flow from operating activities.
Year-End 2015 Proved Reserves
Proved reserves as of December 31, 2015 were 76.4 MMBoe, or 458.1 Bcfe, with 55% comprised of liquids (46% crude oil and 9% NGLs) and 45% natural gas. Total proved reserves at December 31, 2014, excluding the reserves attributable to the Yellow Rose field were 82.7 MMBoe (120.0 MMBoe including the Yellow Rose field). Approximately 75% of our 2015 proved reserves were classified as proved developed producing, 15% as proved developed non-producing and 10% as proved undeveloped.
The 7.6% decline in year-over-year proved reserves (excluding the Yellow Rose field reserves sold in October) was due primarily to the significant reduction in commodity prices and from production, partially offset by increases from revisions, extensions and discoveries. The reduction due to lower commodity prices on reserve balances at December 31, 2015 was estimated at 10.7 MMBoe and production reduced reserve balances by 17.0 MMBoe. Net increases were from revisions of 15.3 MMBoe; extensions and discoveries of 4.1 MMBoe and purchases of 1.0 MMBoe.
Our total proved reserves had an estimated present value of future net revenues discounted at 10% ("PV-10") of $966 million. Our PV-10 after considering future cash outflows related to asset retirement obligations ("ARO"), and our standardized measure of discounted future cash flows were both $614 million as of December 31, 2015. The amounts are the same as no income taxes on future cash flows are estimated due to our current tax position net operating loss carryforwards. Neither PV-10 nor PV-10 after ARO is a financial measure defined under generally accepted accounting principles ("GAAP"). For additional information about our proved reserves and a reconciliation of PV-10 and PV-10 after ARO to the standardized measure of discounted future net cash flows, see our Annual Report on Form 10-K.
Our proved reserves as of December 31, 2015 are summarized below:
Total Equivalent Reserves (2) |
||||||||||||
Classification of Proved Reserves (1) |
Oil |
NGLs |
Natural Gas |
Oil |
% of |
PV-10 | ||||||
Proved developed producing |
23.8 |
5.7 |
168.1 |
57.7 |
75% |
$ 775 | ||||||
Proved developed non-producing |
5.6 |
0.7 |
30.4 |
11.3 |
15% |
128 | ||||||
Total proved developed |
29.4 |
6.4 |
198.5 |
69.0 |
90% |
903 | ||||||
Proved undeveloped |
6.1 |
0.2 |
6.9 |
7.4 |
10% |
63 | ||||||
Total proved |
35.5 |
6.6 |
205.4 |
76.4 |
100% |
$ 966 |
1) |
In accordance with guidelines established by the SEC, our proved reserves as of December 31, 2015 were determined to be economically producible under existing economic conditions, which requires the use of the unweighted arithmetic average of the first-day-of-the-month prices for oil and gas for the period January 2015 through December 2015. PV-10 value excludes the effect of cash outflows for ARO and is a non-GAAP financial measure. For 2015, proved reserves and PV-10 were calculated using average benchmark prices of $46.94 per barrel for oil, $17.60 per barrel for natural gas liquids and $2.50 per Mcf for natural gas, as adjusted for energy content for natural gas, quality, transportation fees and regional price differentials. These prices are significantly higher than more recent prices. |
2) |
MMBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). NGLs are converted to barrels using a ratio of 42 gallons to one barrel. The energy-equivalent ratios do not assume price equivalency, and the energy-equivalent prices for crude oil, NGLs, and natural gas may differ significantly. |
OPERATIONS UPDATE
Offshore Gulf of Mexico:
Ewing Bank 910 (50% WI, operated, deepwater)
The Company recently completed, in two separate zones, the Ewing Bank 954 A-8 well that was drilled from the EW 910 platform. The rig has now been released. This is the second well in a two-well exploration program that was drilled from the EW 910 platform, following the earlier discovery at the ST 320 A-5 well in May 2015. The EW 954 A-8 well reached total depth in December and penetrated a total of 150 feet of measured depth hydrocarbon pay contained in two sands. The well has achieved a gross initial production rate from the lower sand completion of approximately 3,500 Boe per day and is still cleaning up. We also have pre-completed a second zone in the A-8 well, which was actually the primary and larger target zone and plan to place this second completion on production later as the lower completion depletes. W&T is operator of the EW 910 field and owns a 50% working interest in the well.
First Quarter and Full Year 2016 Outlook
Our guidance for the first quarter and full year 2016 is provided in the table below and represents the Company's best estimate of the range of likely future results. Lower full-year production guidance is due primarily to the sale of our Yellow Rose field, while lower guidance for operating expenses is due to reduced activity, lower cost of goods and services and the sale of Yellow Rose. Guidance could be affected by the factors described below in "Forward-Looking Statements."
Estimated Production |
First Quarter 2016 |
Full-Year 2016 | ||
Oil and NGLs (MMBbls) |
2.3 – 2.5 |
8.5 – 9.3 | ||
Natural gas (Bcf) |
9.8 – 10.8 |
37.9 – 41.9 | ||
Total (Bcfe) |
23.2 – 25.6 |
88.8 – 98.2 | ||
Total (MMBoe) |
3.9 – 4.3 |
14.8 – 16.4 | ||
Operating Expenses |
First Quarter 2016 |
Full-Year 2016 | ||
Lease operating expenses |
$41.3– $45.7 |
$166 – $184 | ||
Gathering, transportation & production taxes |
$5 – $6 |
$22 – $24 | ||
General and administrative |
$15.9 – $17.5 |
$61 – $68 | ||
Income tax rate (100% deferred) |
5.4% |
5.4% |
Conference Call Information: W&T will hold a conference call to discuss our financial and operational results on Wednesday, March 9, 2016, at 9:30 a.m. Eastern 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 approximately two hours after the end of the call until March 16, 2016 and may be accessed by calling 201-612-7415 and using the passcode 13629410.
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 offshore fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 900,000 gross acres offshore, including approximately 550,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate offshore. For more information on W&T Offshore, please visit our 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 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 W&T Offshore's Annual Report on Form 10-K for the year ended December 31, 2014 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 our most recent annual report on Form 10-K and in other periodic reports on file with the SEC, available from our website at www.wtoffshore.com.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||||
Condensed Consolidated Statements of Income (Loss) | ||||||||||||||
(Unaudited) | ||||||||||||||
Three Months Ended |
Twelve Months Ended | |||||||||||||
December 31, |
December 31, | |||||||||||||
2015 |
2014 |
2015 |
2014 | |||||||||||
(In thousands, except per share data) | ||||||||||||||
Revenues |
$ |
104,064 |
$ |
196,677 |
$ |
507,265 |
$ |
948,708 | ||||||
Operating costs and expenses: |
||||||||||||||
Lease operating expenses |
49,265 |
75,635 |
192,765 |
264,751 | ||||||||||
Gathering, transportation costs and production taxes |
4,444 |
8,729 |
20,159 |
27,753 | ||||||||||
Depreciation, depletion, amortization and accretion |
67,933 |
130,889 |
394,071 |
511,102 | ||||||||||
Ceiling test write-down of oil and natural gas properties |
32,388 |
- |
987,238 |
- | ||||||||||
General and administrative expenses |
16,072 |
22,722 |
73,110 |
86,999 | ||||||||||
Derivative gain |
(5,222) |
(10,755) |
(14,375) |
(3,965) | ||||||||||
Total costs and expenses |
164,880 |
227,220 |
1,652,968 |
886,640 | ||||||||||
Operating income (loss) |
(60,816) |
(30,543) |
(1,145,703) |
62,068 | ||||||||||
Interest expense: |
||||||||||||||
Incurred |
26,776 |
22,219 |
104,592 |
86,922 | ||||||||||
Capitalized |
(1,246) |
(2,104) |
(7,256) |
(8,526) | ||||||||||
Other (income) expense, net |
2,016 |
(3) |
4,663 |
(208) | ||||||||||
Loss before income tax benefit |
(88,362) |
(50,655) |
(1,247,702) |
(16,120) | ||||||||||
Income tax benefit |
(36,756) |
(17,284) |
(202,984) |
(4,459) | ||||||||||
Net loss |
$ |
(51,606) |
$ |
(33,371) |
$ |
(1,044,718) |
$ |
(11,661) | ||||||
Basic and diluted loss per common share |
$ |
(0.68) |
$ |
(0.44) |
$ |
(13.76) |
$ |
(0.16) | ||||||
Weighted average common shares outstanding |
76,024 |
75,658 |
75,931 |
75,609 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Three Months Ended |
||||||||||||
December 31, |
Variance | |||||||||||
2015 |
2014 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
1,975 |
1,830 |
145 |
7.9% | ||||||||
NGL (MBbls) |
363 |
567 |
(204) |
-36.0% | ||||||||
Oil and NGLs (MBbls) |
2,339 |
2,398 |
(59) |
-2.5% | ||||||||
Natural gas (MMcf) |
10,693 |
13,137 |
(2,444) |
-18.6% | ||||||||
Total oil and natural gas (MBoe) (1) |
4,121 |
4,587 |
(466) |
-10.2% | ||||||||
Total oil and natural gas (MMcfe) (1) |
24,724 |
27,524 |
(2,800) |
-10.2% | ||||||||
Average daily equivalent sales (MBoe/d) |
44.8 |
49.9 |
(5.1) |
-10.2% | ||||||||
Average daily equivalent sales (MMcfe/d) |
268.7 |
299.2 |
(30.5) |
-10.2% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
36.99 |
$ |
70.72 |
$ |
(33.73) |
-47.7% | |||||
NGLs ($/Bbl) |
16.16 |
26.97 |
(10.81) |
-40.1% | ||||||||
Oil and NGLs ($/Bbl) |
33.75 |
60.37 |
(26.62) |
-44.1% | ||||||||
Natural gas ($/Mcf) |
2.19 |
3.81 |
(1.62) |
-42.5% | ||||||||
Barrel of oil equivalent ($/Boe) |
24.84 |
42.46 |
(17.62) |
-41.5% | ||||||||
Natural gas equivalent ($/Mcfe) |
4.14 |
7.08 |
(2.94) |
-41.5% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
11.96 |
$ |
16.49 |
$ |
(4.53) |
-27.5% | |||||
Gathering and transportation costs and production taxes |
1.08 |
1.90 |
(0.82) |
-43.2% | ||||||||
Depreciation, depletion, amortization and accretion |
16.49 |
28.53 |
(12.04) |
-42.2% | ||||||||
General and administrative expenses |
3.90 |
4.95 |
(1.05) |
-21.2% | ||||||||
Adjusted EBITDA |
8.87 |
19.53 |
(10.66) |
-54.6% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.99 |
$ |
2.75 |
$ |
(0.76) |
-27.6% | |||||
Gathering and transportation costs and production taxes |
0.18 |
0.32 |
(0.14) |
-43.8% | ||||||||
Depreciation, depletion, amortization and accretion |
2.75 |
4.76 |
(2.01) |
-42.2% | ||||||||
General and administrative expenses |
0.65 |
0.83 |
(0.18) |
-21.7% | ||||||||
Adjusted EBITDA |
1.48 |
3.26 |
(1.78) |
-54.6% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||||||
Condensed Operating Data | ||||||||||||
(Unaudited) | ||||||||||||
Twelve Months Ended |
||||||||||||
December 31, |
Variance | |||||||||||
2015 |
2014 |
Variance |
Percentage(2) | |||||||||
Net sales volumes: |
||||||||||||
Oil (MBbls) |
7,751 |
7,176 |
575 |
8.0% | ||||||||
NGL (MBbls) |
1,604 |
2,112 |
(508) |
-24.1% | ||||||||
Oil and NGLs (MBbls) |
9,355 |
9,288 |
67 |
0.7% | ||||||||
Natural gas (MMcf) |
46,163 |
50,088 |
(3,925) |
-7.8% | ||||||||
Total oil and natural gas (MBoe) (1) |
17,049 |
17,636 |
(587) |
-3.3% | ||||||||
Total oil and natural gas (MMcfe) (1) |
102,294 |
105,815 |
(3,521) |
-3.3% | ||||||||
Average daily equivalent sales (MBoe/d) |
46.7 |
48.3 |
(1.6) |
-3.3% | ||||||||
Average daily equivalent sales (MMcfe/d) |
280.3 |
289.9 |
(9.6) |
-3.3% | ||||||||
Average realized sales prices: |
||||||||||||
Oil ($/Bbl) |
$ |
45.05 |
$ |
90.96 |
$ |
(45.91) |
-50.5% | |||||
NGLs ($/Bbl) |
17.25 |
34.49 |
(17.24) |
-50.0% | ||||||||
Oil and NGLs ($/Bbl) |
40.28 |
78.13 |
(37.85) |
-48.4% | ||||||||
Natural gas ($/Mcf) |
2.67 |
4.35 |
(1.68) |
-38.6% | ||||||||
Barrel of oil equivalent ($/Boe) |
29.34 |
53.49 |
(24.15) |
-45.1% | ||||||||
Natural gas equivalent ($/Mcfe) |
4.89 |
8.92 |
(4.03) |
-45.2% | ||||||||
Average per Boe ($/Boe): |
||||||||||||
Lease operating expenses |
$ |
11.31 |
$ |
15.01 |
$ |
(3.70) |
-24.7% | |||||
Gathering and transportation costs and production taxes |
1.18 |
1.57 |
(0.39) |
-24.8% | ||||||||
Depreciation, depletion, amortization and accretion |
23.11 |
28.98 |
(5.87) |
-20.3% | ||||||||
General and administrative expenses |
4.29 |
4.93 |
(0.64) |
-13.0% | ||||||||
Adjusted EBITDA |
13.20 |
32.28 |
(19.08) |
-59.1% | ||||||||
Average per Mcfe ($/Mcfe): |
||||||||||||
Lease operating expenses |
$ |
1.88 |
$ |
2.50 |
$ |
(0.62) |
-24.8% | |||||
Gathering and transportation costs and production taxes |
0.20 |
0.26 |
(0.06) |
-23.1% | ||||||||
Depreciation, depletion, amortization and accretion |
3.85 |
4.83 |
(0.98) |
-20.3% | ||||||||
General and administrative expenses |
0.71 |
0.82 |
(0.11) |
-13.4% | ||||||||
Adjusted EBITDA |
2.20 |
5.38 |
(3.18) |
-59.1% |
(1) MMcfe and MBoe are determined using the ratio of six Mcf of natural gas to one Bbl of crude oil, condensate or NGLs (totals may not compute due to rounding). The conversion ratio does not assume price equivalency and the price on an equivalent basis for oil, NGLs and natural gas may differ significantly. |
(2) Variance percentages are calculated using rounded figures and may result in slightly different figures for comparable data. |
W&T OFFSHORE, INC. AND SUBSIDIARIES | |||||||
Condensed Consolidated Balance Sheets | |||||||
(Unaudited) | |||||||
December 31, |
December 31, | ||||||
2015 |
2014 | ||||||
(In thousands, except | |||||||
share data) | |||||||
Assets |
|||||||
Current assets: |
|||||||
Cash and cash equivalents |
$ |
85,414 |
$ |
23,666 | |||
Receivables: |
|||||||
Oil and natural gas sales |
35,005 |
67,242 | |||||
Joint interest and other |
22,012 |
43,645 | |||||
Total receivables |
57,017 |
110,887 | |||||
Prepaid expenses and other assets |
26,879 |
36,347 | |||||
Total current assets |
169,310 |
170,900 | |||||
Property and equipment – at cost: |
|||||||
Oil and natural gas properties and equipment (full cost method, of which $18,595 at |
|||||||
December 31, 2015 and $109,824 at December 31, 2014 were excluded from amortization) |
7,902,494 |
8,045,666 | |||||
Furniture, fixtures and other |
20,802 |
23,269 | |||||
Total property and equipment |
7,923,296 |
8,068,935 | |||||
Less accumulated depreciation, depletion and amortization |
6,933,247 |
5,575,078 | |||||
Net property and equipment |
990,049 |
2,493,857 | |||||
Deferred income taxes |
27,595 |
- | |||||
Restricted deposits for asset retirement obligations |
15,606 |
15,444 | |||||
Other assets |
5,462 |
9,307 | |||||
Total assets |
$ |
1,208,022 |
$ |
2,689,508 | |||
Liabilities and Shareholders' Equity |
|||||||
Current liabilities: |
|||||||
Accounts payable |
$ |
109,797 |
$ |
194,109 | |||
Undistributed oil and natural gas proceeds |
21,439 |
37,009 | |||||
Asset retirement obligations |
84,335 |
36,003 | |||||
Accrued liabilities |
11,922 |
17,377 | |||||
Total current liabilities |
227,493 |
284,498 | |||||
Long-term debt |
1,196,855 |
1,352,120 | |||||
Asset retirement obligations, less current portion |
293,987 |
354,565 | |||||
Deferred income taxes |
- |
175,326 | |||||
Other liabilities |
16,178 |
13,691 | |||||
Commitments and contingencies |
- |
- | |||||
Shareholders' equity: |
|||||||
Common stock, $0.00001 par value; 118,330,000 shares authorized; 79,375,662 issued and 76,506,489 outstanding at December 31, 2015; 78,768,588 issued and 75,899,415 outstanding at December 31, 2014 |
1 |
1 | |||||
Additional paid-in capital |
423,499 |
414,580 | |||||
Retained earnings (deficit) |
(925,824) |
118,894 | |||||
Treasury stock, at cost |
(24,167) |
(24,167) | |||||
Total shareholders' equity (deficit) |
(526,491) |
509,308 | |||||
Total liabilities and shareholders' equity |
$ |
1,208,022 |
$ |
2,689,508 |
W&T OFFSHORE, INC. AND SUBSIDIARIES | ||||||||
Condensed Consolidated Statements of Cash Flows | ||||||||
(Unaudited) | ||||||||
Twelve Months Ended |
||||||||
December 31, |
||||||||
2015 |
2014 |
|||||||
(In thousands) |
||||||||
Operating activities: |
||||||||
Net loss |
$ |
(1,044,718) |
$ |
(11,661) |
||||
Adjustments to reconcile net loss to net cash provided by operating activities: |
||||||||
Depreciation, depletion, amortization and accretion |
394,071 |
511,102 |
||||||
Ceiling test write-down of oil and natural gas properties |
987,238 |
- |
||||||
Debt issuance costs write-down/amortization of debt items |
4,411 |
701 |
||||||
Share-based compensation |
10,242 |
14,744 |
||||||
Derivative gain |
(14,375) |
(3,965) |
||||||
Cash payments on derivative settlements |
6,703 |
(5,318) |
||||||
Deferred income taxes |
(203,272) |
(4,760) |
||||||
Asset retirement obligation settlements |
(32,555) |
(74,313) |
||||||
Changes in operating assets and liabilities |
24,809 |
47,443 |
||||||
Net cash provided by operating activities |
132,554 |
473,973 |
||||||
Investing activities: |
||||||||
Acquisitions of property interests in oil and natural gas properties |
- |
(72,234) |
||||||
Investment in oil and natural gas properties and equipment |
(230,161) |
(554,378) |
||||||
Changes in operating assets and liabilities associated with investing activities |
(55,425) |
37,450 |
||||||
Proceeds from sales of assets and other, net |
372,939 |
- |
||||||
Purchases of furniture, fixtures and other |
(1,278) |
(3,340) |
||||||
Net cash provided by (used in) investing activities |
86,075 |
(592,502) |
||||||
Financing activities: |
||||||||
Borrowings of long-term debt |
263,000 |
556,000 |
||||||
Repayments of long-term debt |
(710,000) |
(399,000) |
||||||
Issuance of 9.00% Term Loan |
297,000 |
- |
||||||
Dividends to shareholders |
- |
(30,260) |
||||||
Debt issuance costs |
(6,669) |
- |
||||||
Other |
(212) |
(345) |
||||||
Net cash provided (used in) by financing activities |
(156,881) |
126,395 |
||||||
Increase in cash and cash equivalents |
61,748 |
7,866 |
||||||
Cash and cash equivalents, beginning of period |
23,666 |
15,800 |
||||||
Cash and cash equivalents, end of period |
$ |
85,414 |
$ |
23,666 |
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 Loss to Net Loss Excluding Special Items
"Net Loss Excluding Special Items" does not include the derivative (gain) loss, write-off of debt issuance and other non-operating costs, contingent assessment provision, ceiling test write-down of oil and natural gas properties and associated tax effects. Net 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, |
|||||||||||||||
2015 |
2014 |
2015 |
2014 |
|||||||||||||
(In thousands, except per share amounts) | ||||||||||||||||
(Unaudited) | ||||||||||||||||
Net loss |
$ |
(51,606) |
$ |
(33,371) |
$ |
(1,044,718) |
$ |
(11,661) |
||||||||
Derivative gain |
(5,222) |
(10,755) |
(14,375) |
(3,965) |
||||||||||||
Write off of debt issuance and other non operating costs |
4,378 |
- |
7,542 |
- |
||||||||||||
Contingent assessment provision |
- |
- |
1,000 |
- |
||||||||||||
Ceiling test write-down of oil and natural gas properties |
32,388 |
- |
987,238 |
- |
||||||||||||
Income tax adjustment for above items at current period tax rate… |
(13,375) |
3,667 |
(159,969) |
1,098 |
||||||||||||
Net loss excluding special items |
$ |
(33,437) |
$ |
(40,459) |
$ |
(223,282) |
$ |
(14,528) |
||||||||
Basic and diluted loss per common share, excluding special items |
$ |
(0.44) |
$ |
(0.54) |
$ |
(2.94) |
$ |
(0.20) |
||||||||
W&T OFFSHORE, INC. AND SUBSIDIARIES
Non-GAAP Information
Reconciliation of Net Loss to Adjusted EBITDA
We define EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization, and accretion and ceiling test write-down of oil and natural gas properties. Adjusted EBITDA excludes the (gain) loss related to our derivatives, write off of debt issuance and other non-operating costs, and contingent assessment provision. 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 (loss), 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 consolidated net loss to consolidated EBITDA and Adjusted EBITDA along with our Adjusted EBITDA margin.
Three Months Ended |
Twelve Months Ended |
|||||||||||||||
December 31, |
December 31, |
|||||||||||||||
2015 |
2014 |
2015 |
2014 |
|||||||||||||
(In thousands) | ||||||||||||||||
(Unaudited) | ||||||||||||||||
Net loss |
$ |
(51,606) |
$ |
(33,371) |
$ |
(1,044,718) |
$ |
(11,661) |
||||||||
Income tax benefit |
(36,756) |
(17,284) |
(202,984) |
(4,459) |
||||||||||||
Net interest expense |
25,419 |
20,116 |
97,205 |
78,194 |
||||||||||||
Depreciation, depletion, amortization and accretion |
67,933 |
130,889 |
394,071 |
511,102 |
||||||||||||
Ceiling test write-down of oil and natural gas properties |
32,388 |
- |
987,238 |
- |
||||||||||||
EBITDA |
37,378 |
100,350 |
230,812 |
573,176 |
||||||||||||
Adjustments: |
||||||||||||||||
Derivative gain |
(5,222) |
(10,755) |
(14,375) |
(3,965) |
||||||||||||
Write off of debt issuance and other non operating costs |
4,378 |
- |
7,542 |
- |
||||||||||||
Contingent assessment provision |
- |
- |
1,000 |
- |
||||||||||||
Adjusted EBITDA |
$ |
36,534 |
$ |
89,595 |
$ |
224,979 |
$ |
569,211 |
||||||||
Adjusted EBITDA Margin |
35% |
46% |
44% |
60% |
SOURCE W&T Offshore, Inc.
HOUSTON, Feb. 26, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) ("W&T" or the "Company") today announced that it has borrowed approximately $340 million under the Company's Bank Credit Facility, to be used for general corporate purposes. Including these funds, the Company's current cash position totals approximately $447 million.
"W&T Offshore has a strong liquidity position and continues to deliver solid operational results," said Tracy W. Krohn, Chairman and Chief Executive Officer. "We continue to reduce costs and note that our exploration success for nearly three years has been one hundred percent. We expect to place our recent discovery, the Ewing Bank 954 A-8, on line in March 2016."
The Company has retained Kirkland & Ellis LLP as its legal advisor and Evercore as its financial advisor to assist the Board of Directors and management team.
About W&T Offshore
W&T is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 offshore fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 900,000 gross acres offshore, including approximately 550,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate offshore. For more information on W&T, please visit our website at www.wtoffshore.com.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 | |
Meaghan Repko or Joe Millsap |
||
Joele Frank, Wilkinson Brimmer Katcher |
||
212-895-8668 |
SOURCE W&T Offshore, Inc.
HOUSTON, Feb. 10, 2016 /PRNewswire/ -- W&T Offshore, Inc. (NYSE: WTI) announced today that it will release its fourth quarter 2015 financial and operational results after the market closes on Tuesday, March 8. In conjunction with the release, the Company has scheduled a conference call, which will also be broadcast live over the Internet, on Wednesday, March 9 at 9:30 a.m. Eastern Time (8:30 a.m. Central Time).
By Phone: |
Dial 1-412-902-0030 at least 10 minutes before the call. A telephone replay will be available through March 16 by dialing 1-201-612-7415 and using the passcode 13629410. |
By Webcast: |
Visit the Investor Relations page of W&T's website at www.wtoffshore.com under "Presentations." A replay will be available shortly after the call. |
The Company also announced that its 2016 Annual Meeting of Shareholders will be held at 8:00 a.m. Central Time on May 4, 2016, at the offices of the Company, Nine Greenway Plaza, Suite 300, Houston, Texas 77046. Shareholders of record at the close of business on March 9, 2016 are entitled to receive notice of the meeting and to vote the shares of W&T Offshore common stock they held as of that date.
About W&T Offshore
W&T Offshore, Inc. is an independent oil and natural gas producer with operations offshore in the Gulf of Mexico. We have grown through acquisitions, exploration and development and currently hold working interests in approximately 54 fields in federal and state waters (50 producing and four fields capable of producing). W&T currently has under lease approximately 900,000 gross acres, including approximately 550,000 gross acres on the Gulf of Mexico Shelf and approximately 350,000 gross acres in the deepwater. A majority of our daily production is derived from wells we operate. For more information on W&T Offshore, please visit our website at www.wtoffshore.com.
CONTACT: |
Lisa Elliott |
Danny Gibbons |
Dennard Lascar Associates |
SVP & CFO | |
713-529-6600 |
713-624-7326 |
SOURCE W&T Offshore, Inc.
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