Project: Canadian Mainline Tolling Option
Firm Commitment: 52.8 Mmcf/d
DENVER, June 25, 2019 /PRNewswire/ -- The oil and gas companies presenting at EnerCom's 24th annual The Oil & Gas Conference® are largely independent exploration and production companies developing oil and gas assets. The conference affords oil and gas analysts, portfolio managers, family offices and other buyside investors an extensive view of U.S. and Canadian shale companies, Latin American conventionals and U.S. offshore drillers–all in one place: Denver, Colorado.
The 24th edition of one of the industry's largest independent upstream oil and gas-focused conferences takes place Aug. 11-14, 2019, at Denver, Colorado's downtown Westin hotel.
Additional Presenting Companies on Day Two of the 2019 EnerCom Conference
The second day of the EnerCom conference includes the following oil and gas company management teams:
The daily schedule of presenters is also 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.
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.
On Aug. 13th, Harvard PhD (Economics) and CIBC Capital Markets CIBC (NYSE: CM) Chief Economist Avery Shenfeld, repeat winner of Dow Jones MarketWatch forecasting award and Bloomberg Markets' awards for forecasting accuracy, will deliver his views on where oil and gas markets are headed.
Tuesday's keynote luncheon is a "Fireside Chat" with outspoken, legendary oilman Continental Resources (NYSE: CLR) Chairman and CEO Harold Hamm.
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 – 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.
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SOURCE EnerCom, Inc.
(TSX: AAV, NYSE: AAV)
CALGARY, Aug. 31, 2018 /PRNewswire/ - On August 31, 2018 the board of directors (the "Board") of Advantage Oil & Gas Ltd. ("Advantage" or the "Company") approved the delisting of the Company's common shares (the "Common Shares") from the New York Stock Exchange ("NYSE"). On August 31, 2018, the Company notified the NYSE of its intention to file a Form 25 with the Securities and Exchange Commission (the "SEC") on or about September 10, 2018 to effect the voluntary delisting from the NYSE of the Common Shares. On or about September 20, 2018 the Company intends to file a Form 15 with the SEC to terminate the registration of the Common Shares and suspend the Company's reporting obligations under the Securities Exchange Act of 1934, as amended (the "Exchange Act").
The Company made the decision to delist the Common Shares from the NYSE and terminate registration under the Exchange Act following the Company's review and careful consideration of the administrative burden and the costs and benefits of being a U.S. reporting company. The savings derived from this change are expected to be financially meaningful. Advantage will continue to comply with its Canadian continuous disclosure obligations and the Common Shares will continue to trade on the Toronto Stock Exchange.
View original content with multimedia:http://www.prnewswire.com/news-releases/advantage-announces-us-delisting-and-deregistration-300705595.html
SOURCE Advantage Oil & Gas Ltd.
Commissioning of Glacier Gas Plant Expansion to 400 mmcf/d Creates Significant Available Processing Capacity for Future Growth
(TSX: AAV, NYSE: AAV)
CALGARY, Aug. 2, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") successfully commissioned its major gas plant expansion project in the second quarter of 2018 at the Corporation's 100% owned Glacier sour gas facility. This is a strategic milestone in the development of Advantage's Montney resource as our expanded Glacier gas plant now contains significant spare capacity to accommodate future liquids-rich production growth from Glacier and our additional land blocks at Valhalla, Wembley/Pipestone and Progress. The expansion increased processing capacity of raw gas to 400 mmcf/d (second largest Alberta producer owned licensed sour gas plant) and shallow cut liquids extraction to 6,800 bbls/d, providing approximately 125 mmcf/d of current spare raw gas processing capacity. This spare capacity supports Advantage's higher focus on increasing its liquid-rich production and also provides flexibility to readily increase natural gas production in response to price improvements.
In April 2018, Advantage provided updated guidance which included moderated natural gas production in response to low prices and confirmed plans to redirect more of its future capital investments into the Corporation's significant and growing inventory of liquids-rich drilling opportunities.
During the second quarter of 2018, average production was 212.1 mmcfe/d (35,352 boe/d), including liquids production of 1,067 bbls/d (70% condensate), with total per unit cash costs of $1.21/mcfe. Total cash costs are expected to return to approximately $1.10/mcfe to $1.20/mcfe, including operating costs of $0.24/mcfe to $0.28/mcfe, for the remainder of 2018 due to higher production rates. Capital expenditures during the quarter of $25.8 million were largely funded from cash flow of $23.2 million ($0.12/share) despite a 58% decrease in the AECO daily natural gas price. The Corporation renewed its annual credit facility of $400 million with improved borrowing terms and maintained a strong balance sheet with a total debt to trailing 12 month cash flow ratio of 1.7. Current production is approximately 270 mmcfe/d (45,000 boe/d) including liquids production of approximately 1,700 bbls/d.
Advantage's increased focus on liquids-rich activities during the second half of 2018 includes commencing production from 5 standing liquids-rich Middle Montney wells and the commencement of a drilling program which includes 10 Middle Montney wells in east Glacier and an additional 5 liquids-rich wells at Valhalla. Construction plans were finalized for Advantage's new Valhalla facility which includes a compressor station and liquids handling hub with project completion scheduled in the fourth quarter of 2018.
At our ultra-rich liquids asset at Wembley/Pipestone, we advanced work on selecting routes to extend Advantage's current gathering pipeline system into this area and have secured a firm third party processing arrangement for up to 10 mmcf/d of capacity beginning in the latter half of 2019 for added flexibility and optionality. Our excitement continues to build in regard to the upside value of Advantage's entire Wembley/Pipestone land block based on recently released industry well test information on each side of our asset.
The Corporation strengthened its commodity hedging position by monetizing certain in-the-money 2018 and 2019 NYMEX-AECO differential swaps and applying the proceeds towards the acquisition of 62 mmcf/d of AECO monthly settled puts at $1.42 per mcf for June through September 2018 and 62 mmcf/d of enhanced AECO fixed price swaps at $1.77 per mcf for the April 2019 to October 2019 period. The restructuring of these transactions provides Advantage with greater price and cash flow certainty during planned third party maintenance activities which have and are anticipated to create significant gas price volatility. For the second half of 2018 the Corporation has total fixed price hedges for 112 mmcf/d with 77 mmcf/d at an AECO average price of $2.29 Cdn/mcf and 35 mmcf/d at a Dawn average price of $2.85 US/mmbtu. In 2019, Advantage has 81 mmcf/d hedged with 75 mmcf/d at an AECO average price of $2.26 Cdn/mcf and 6 mmcf/d at a Dawn average price of $3.13 US/mmbtu. The Corporation's AECO price exposure is estimated by Management to be approximately 25% of total revenue through to 2020 as a result of the Advantage's revenue diversification program.
Operations Update
Glacier
Six Middle Montney and two Lower Montney wells located on an eight well pad in the western portion of Glacier were completed in the first quarter of 2018 and were designed to evaluate the impact of tighter frac spacing in an area where there are few Middle Montney wells.
The six Middle Montney wells on this pad contained an average frac count of 34 stages per well representing a 76% increase over our previous Middle Montney wells. Four of the six wells have been placed on production with flow duration ranging from 30 to 100 days. On average, the wells have flowed 62 days at an average restricted rate of 8.3 mmcf/d representing a 62% increase over our unrestricted type curve. Production rates remain restricted on all wells with a current average flowing wellhead pressure of 8,600 kPa
The two Lower Montney wells have been on restricted production for 17 days averaging 7.5 mmcf/d with current flowing pressures of 10,000 kPa which significantly exceeds the flowing pressure assumption in our average dry gas type curve.
We have spud the first well of a 10 well Middle Montney pad located in east Glacier where initial C3+ liquid yields have been approximately 50 to 80 bbls/mmcf (approximately 50% C5+) and the knowledge gained in recent well completions in the western portion of Glacier will be used to further enhance well performance.
Valhalla
One of the standing Middle Montney wells was placed on production during the second quarter of 2018 and has produced under restricted flow at approximately 6 mmcf/d (20% above Advantage's Middle Montney average well type curve) at a flowing pressure of 6,900 kPa for 73 days. Well production from Valhalla will remain restricted until Advantage's new Valhalla facility, which includes 40 mmcf/d of compression and liquids handling equipment, is completed in the fourth quarter of 2018. This facility will increase the throughput capacity of our existing pipeline connecting Valhalla to Advantage's Glacier gas plant. Two standing Upper Montney wells will also be brought on-production after the Valhalla facility is completed.
Advantage will drill a new 5 well liquids-rich pad at Valhalla as part of our upcoming winter drilling program.
Wembley/Pipestone
Construction work is scheduled to begin in August 2018 on the tie-in of Advantage's first delineation well at 12-25-72-8W6. This well will be tied-in to a third party producer facility on a 'best-efforts' processing basis as available capacity continues to be increasingly constrained due to industry successes in this prolific condensate/oil fairway.
We continue to advance work towards extending Advantage's current gathering pipelines into this area and have secured a firm third party processing arrangement beginning in the latter half of 2019 that can provide up to 10 mmcf/d of capacity for added optionality. Advantage's facility and pipeline construction is expected to occur during the first half of 2020; although, Advantage will be prepared to commence this work earlier if the timeline can be shortened.
Recently released industry wells which offset our Wembley/Pipestone land block demonstrate similar results to our 12-25 well which was production tested earlier this year at 1,312 boe/d with 819 bbls/d of liquids including 624 bbls/d of wellhead condensate/oil and 2.9 mmcf/d of gas.
Looking Forward
Advantage continues to build operational flexibility with a significant Montney resource of low cost prolific natural gas and liquids including condensate and oil. This solid foundation which includes 200 net sections of Montney lands, 100% owned gas plant and an expanding pipeline infrastructure combined with an industry leading low cost structure is well positioned to create long term value. Advantage will continue to closely monitor market conditions and respond promptly and responsibly in order to optimize the allocation of our capital investments.
Second Quarter 2018
Operating and Financial Summary
Three months ended |
Six months ended | |||||||||||
Financial and Operating Highlights |
June 30 |
June 30 | ||||||||||
2018 |
2017 |
2018 |
2017 | |||||||||
Financial ($000, except as otherwise indicated) |
||||||||||||
Sales including realized hedging (3) |
$ |
45,319 |
$ |
69,169 |
$ |
118,697 |
$ |
142,126 | ||||
Net income (loss) and comprehensive income (loss) |
$ |
(15,294) |
$ |
18,339 |
$ |
(5,191) |
$ |
60,588 | ||||
per basic share |
$ |
(0.08) |
$ |
(0.05) |
$ |
(0.03) |
$ |
0.33 | ||||
Funds from operations(1) |
$ |
23,160 |
$ |
48,625 |
$ |
72,042 |
$ |
102,597 | ||||
per basic share |
$ |
0.12 |
$ |
0.26 |
$ |
0.39 |
$ |
0.55 | ||||
Net capital expenditures |
$ |
25,761 |
$ |
31,462 |
$ |
103,397 |
$ |
85,253 | ||||
Working capital deficit |
$ |
3,206 |
$ |
6,950 |
$ |
3,206 |
$ |
6,950 | ||||
Bank indebtedness |
$ |
250,189 |
$ |
134,128 |
$ |
250,189 |
$ |
134,128 | ||||
Basic weighted average shares (000) |
186,190 |
185,790 |
186,077 |
185,319 | ||||||||
Operating |
||||||||||||
Daily Production |
||||||||||||
Natural gas (mcf/d) |
205,712 |
225,844 |
219,009 |
228,363 | ||||||||
Liquids (bbls/d) |
1,067 |
1,098 |
1,086 |
1,124 | ||||||||
Total mcfe/d |
212,114 |
232,432 |
225,525 |
235,107 | ||||||||
Total boe/d |
35,352 |
38,739 |
37,588 |
39,185 | ||||||||
Average prices (including hedging) |
||||||||||||
Natural gas ($/mcf) (3) |
$ |
2.05 |
$ |
3.09 |
$ |
2.65 |
$ |
3.17 | ||||
Liquids ($/bbl) |
$ |
72.32 |
$ |
57.27 |
$ |
69.17 |
$ |
55.47 | ||||
Cash netbacks ($/mcfe)(1) |
||||||||||||
Sales of natural gas and liquids from production |
$ |
1.94 |
$ |
3.16 |
$ |
2.34 |
$ |
3.17 | ||||
Net sales of natural gas purchased from third parties(1) |
0.06 |
- |
0.03 |
- | ||||||||
Realized gains on derivatives |
0.41 |
0.11 |
0.57 |
0.17 | ||||||||
Royalty expense |
0.06 |
(0.15) |
- |
(0.13) | ||||||||
Operating expense |
(0.34) |
(0.27) |
(0.33) |
(0.25) | ||||||||
Transportation expense |
(0.63) |
(0.37) |
(0.60) |
(0.37) | ||||||||
Operating netback(1) |
1.50 |
2.48 |
2.01 |
2.59 | ||||||||
General and administrative |
(0.13) |
(0.12) |
(0.10) |
(0.11) | ||||||||
Settlement of Performance Awards |
(0.03) |
- |
(0.01) |
- | ||||||||
Finance expense |
(0.14) |
(0.07) |
(0.12) |
(0.08) | ||||||||
Other income |
- |
0.01 |
- |
- | ||||||||
Cash netbacks(1) |
$ |
1.20 |
$ |
2.30 |
$ |
1.78 |
$ |
2.40 |
(1) |
Non-GAAP Measure which may not be comparable to similar non-GAAP measures used by other entities. |
(2) |
Based on basic weighted average shares outstanding. |
(3) |
Excludes net sales of natural gas purchased from third parties. |
The Corporation's unaudited interim condensed consolidated financial statements for the three and six months ended June 30, 2018 together with the notes thereto, and Management's Discussion and Analysis for the three and six months ended June 30, 2018 have been filed on SEDAR and with the SEC and are available on the Corporation's website at http://www.advantageog.com/investors/financial-reports/financial-reports-2018.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, completion of expansion of the Corporation's Glacier gas plant, including the anticipated raw processing capacity and shallow cut propane plus liquids extraction capacity following such expansion; Advantage's expectation that the expansion of the Corporation's Glacier gas plant will support anticipated production growth; Advantage's focus on increasing liquids production; Advantage's ability to increase natural gas production in response to commodity price improvements; Advantage's drilling plans, including its plans to redirect more of its future capital investments into the liquids-rich drilling opportunities; the impact of third party processing on Advantage; the impact of third party maintenance activities of gas volatility; the Corporation's AECO price exposure; future well performance; the results of future operations, including the expected total production and liquids production; restrictions on well production at Valhalla; the timing of bringing certain Upper-Montney wells onto production; the anticipated timing of facility and pipeline construction, the tie-in of certain wells as well as Advantage's ability to begin construction earlier if necessary; Advantage's capital program for 2018, including the expected timing of incurring capital expenditures; the factors that Advantage believes will provide Advantage with the ability to respond promptly and responsibly to market conditions; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; failure to achieve production targets on timelines anticipated or at all; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; individual well productivity; lack of available capacity on pipelines; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; delays in completion of the facility at Valhalla; delays in construction and completion of other infrastructure projects; that test results are not indicative of future production rates; lack of available capacity on pipelines; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form dated March 5, 2018, which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: timing of regulatory approvals; conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; well costs; expected annual production growth rates; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2018 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2018 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains a number of oil and gas metrics, including operating netbacks, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes.
References in this press release to flow rates and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The following abbreviations used in this press release have the meanings set forth below.
|
|
bbls/d boe |
barrels per day barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
GJ/d |
gigajoules per day |
mboe |
thousand barrels of oil equivalent |
mcf |
thousand cubic feet |
mcf/d |
thousand cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mcfe/d |
thousand cubic feet equivalent per day on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf/d |
million cubic feet per day |
mmcfe/d |
million cubic feet equivalent per day |
Non-GAAP Measures
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include funds from operations, operating netbacks, cash netbacks, cash costs and total debt to annualized cash flow ratio. Funds from operations, as presented, is based on cash provided by operating activities, before expenditures on decommissioning liability and changes in non-cash working capital, reduced for finance expense excluding accretion. Management believes these adjustments to cash provided by operating activities increase comparability between reporting periods. Operating netback is calculated by adding natural gas and liquids sales with realized gains and losses on derivatives and subtracting royalty expense, operating expense and transportation expense. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period.
Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
View original content:http://www.prnewswire.com/news-releases/advantage-announces-second-quarter-2018-operating--financial-results-300691604.html
SOURCE Advantage Oil & Gas Ltd.
DENVER, Aug. 1, 2018 /PRNewswire/ -- Regardless of whether your area of interest in the U.S. energy sector is the shale plays and companies drilling the U.S. basins, offshore drilling in the Gulf of Mexico, oil pipelines, LNG exports, Texas-sourced frac sand, oilfield services or new oilfield technologies, the 23rd annual EnerCom conference will deliver the best of the industry to the Denver Downtown Westin Hotel Denver Aug. 19-22, 2018.
The combined market value of the presenting public companies is more than $220 billion and the publicly-traded energy companies represent a combined enterprise value of more than $275 billion—55% higher than last year.
Several privately held E&Ps and related energy service companies will be at the conference in force as well this year, participating in a variety of panels at the conference. Conference attendees have a rare opportunity to hear from several large private operators who—unlike their publicly traded counterparts—often say nothing in public about their operations.
Among the private oil companies participating in the conference is Anschutz Exploration, a large operator with assets in the Powder River and Washakie Basins of Wyoming, the Piceance and DJ Basins of Colorado and the Unita Basin of Utah. Other private drillers include Permian producer Felix Energy, DJ Basin producer Great Western Oil & Gas, conventional Piceance gas producer Caerus Oil and Gas, and Powder River and Green River Basin operator Samson Resources II.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, 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 2017, EnerCom managed more than 2,100 one-on-one meeting requests. Buyside investors may request meetings on the conference website or contact EnerCom for more information at 303-296-8834.
How to Register: Investment professionals and oil and gas companies can register for the event through the conference website.
2018 Presenting Companies: The Oil & Gas Conference® 2018 presenting companies consist of the following:
Looking at basin and sector, the 2018 EnerCom conference presenting companies and companies participating in panels break out as follows (list is subject to change prior to the conference– please refer to The Oil & Gas Conference website for an updated schedule of presenting companies):
Exploration & Production and Other Energy Companies by Focus Area and Sector
Bakken/Three Forks
Eagle Ford
Permian Basin
Woodford & Other Mid-Continent – SCOOP/STACK
Marcellus/Utica
Niobrara
Gulf of Mexico/Offshore
Haynesville
Pinedale – Jonah Field – Uinta Basin
Enhanced Oil Recovery
Canadian E&Ps
International E&Ps
LNG Export Projects
Oilfield Service Companies
Midstream
Mineral, Royalty, Infrastructure Holders, Acquisition Companies
Private Companies – E&Ps, Midstream, Energy Data and Technology, Energy Capital, Government Energy Agencies
A work-in-progress schedule of the 2018 presenting companies is posted on the conference website and is regularly updated.
Sponsors of The Oil & Gas Conference®
EnerCom History and Sponsors: EnerCom, Inc. founded The Oil & Gas Conference® in 1996. It is the oldest and largest independent energy investment conference in Denver.
Global sponsors of EnerCom's conferences are Netherland, Sewell & Associates; RS Energy Group; Moss Adams; and Preng & Associates.
Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; SMBC; Opportune LLP; Petrie Partners; EnergyNet; McGriff, Seibels & Williams, Inc.; Energy Intelligence; and TGS.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, 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 upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Feb. 27-28, 2019
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 RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.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 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 AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
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 Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
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 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.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
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.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE.
We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
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 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 Wells Fargo & Company
Wells Fargo & Company 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.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.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 Opportune LLP
Founded in 2005, Opportune is a leading global energy consulting firm specializing in adding value to clients across the energy industry, including upstream, midstream, downstream, power and gas, commodities trading and oilfield services.
Since we are not an audit firm, we are advocates of our clients and are not subject to the restrictions placed on other firms by regulatory bodies. Using our extensive knowledge of all sectors of the energy industry, we work with clients to provide comprehensive solutions to their operational and financial challenges.
Our practice areas include complex financial reporting, dispute resolution, enterprise risk, outsourcing, process and technology, reserve engineering and geosciences, restructuring, strategy and organization, tax, transactional due diligence and valuation. Opportune LLP is not a CPA firm.
Opportune's corporate headquarters are in Houston, Texas. The firm also has offices in Dallas, Denver, New York City, Tulsa, and the UK. For more information please call Ashley Hunt, Marketing Coordinator,
713.490.5050 and visit the web site https://opportune.com/.
About Petrie Partners, LLC
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.
The firm was formed in 2011 (as Strategic Energy Advisors) by senior bankers formerly with Bank of America Merrill Lynch and Petrie Parkman & Co., an investment bank that built a reputation as a most trusted advisor to energy clients during the nearly two decades leading up to its merger into Merrill Lynch in 2006.
Through tenure with Petrie Parkman, Merrill Lynch and Bank of America Merrill Lynch, the senior members of the Petrie team bring to bear an average of more than 25 years of energy investment banking experience, including over 300 energy M&A and capital raising transactions representing over $350 billion of aggregate consideration.
For information about the firm, please visit www.petrie.com or call the firm's Denver office (303.953.6768) or the Houston office (713.659.0760).
About EnergyNet
EnergyNet is the only continuous oil and gas auction and sealed bid transaction service that facilitates the sale of producing working interests (operated and non-operated), overrides, royalties, mineral interests, and non-producing leasehold. EnergyNet is a continuous oil and gas property marketplace with due diligence and bidding available 24/7/365, where auctions and sealed bid packages close weekly. Most of the properties EnergyNet sells are located in the lower 48 United States and typically range in value from $1,000 to $100,000,000.
Details about how to buy and sell oil and gas properties using the EnergyNet online auction service are available on the website at https://www.energynet.com/.
About McGriff, Seibels & Williams, Inc.
McGriff, Seibels & Williams is one of the most progressive insurance brokerage firms in the United States, leading the way with innovative programs to protect clients' financial interests. Services include construction risk, energy and marine, surety, employee benefits and financial services. McGriff's Energy & Marine Division offers specialty services for clients with worldwide operations and potentially catastrophic exposures. Our expertise in this niche industry has made us one of the largest independent energy brokers in the U.S. and one of the top five energy brokers worldwide.
Our client base includes more than 50 electric/gas utility and merchant energy companies, several coal mining companies, and more than 70 E&P companies. It also includes the Strategic Petroleum Reserve and numerous oilfield service companies, including vessel operators, offshore drilling companies, and international marine construction companies.
We will structure and implement a domestic or foreign program for virtually any type of energy-related risk. We have more than 125 professionals in our energy division. Using alternative risk transfer and traditional insurance solutions, we determine the appropriate combination of coverage and risk assumption.
Please contact the company through the website or by calling 800 476 - 2211.
About Energy Intelligence
Energy Intelligence has been a leading independent provider of objective insight, unbiased analysis and reliable data for over 60 years. With offices in New York, London, Houston, Dubai, Moscow, Washington, Singapore and Brussels, we provide decision-makers with critically important information on issues and events affecting the global energy complex.
Our benchmark Information Services, Petroleum Intelligence Weekly, Oil Daily, Natural Gas Week, World Gas Intelligence and Energy Compass, are produced by highly experienced journalists, and our research reports and advisory services are provided by highly regarded analysts and economists.
Information on Energy Intelligence is available at the company website: https://www.energyintel.com/pages/non-subscriber.aspx
About TGS
TGS was founded in Houston in 1981 and over time built the dominant 2D multi-client data library in the Gulf of Mexico. The company expanded further into North America and West Africa and added a substantial 3D portfolio in the Gulf of Mexico.
Also in 1981, NOPEC was founded in Oslo and began building an industry-leading multi-client 2D database in the North Sea, with additional operations in Australia and the Far East. In 1997, NOPEC went public on the Oslo Stock Exchange. In 1998, the companies merged to form TGS-NOPEC Geophysical Company (TGS), creating a winning combination for investors, customers and employees. Since then, TGS has set the standard for geoscientific data around the world.
Additional information is available at the company website: http://www.tgs.com/about-tgs/company-history/ .
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SOURCE EnerCom, Inc.
DENVER, July 25, 2018 /PRNewswire/ -- An impressive roster of CEOs across the upstream and oilfield service and technology spectrum will be at the Denver Downtown Westin Hotel Aug. 20, 21 and 22, 2018, to give presentations at EnerCom's The Oil & Gas Conference®.
EnerCom conference E&Ps are producing more than 3.2 million barrels of oil per day. The presenting North American shale E&Ps, other explorers and producers, international E&Ps, and global oilfield service and technology companies represent a combined market value of $203 billion and a combined enterprise value of $252 billion—53% higher than last year.
As to basin and sector, the 2018 EnerCom conference presenting companies break out as follows (list is subject to change prior to conference– please refer to The Oil & Gas Conference website for an updated schedule of presenting companies):
Exploration & Production, Oilfield Service Companies by Focus Area and Sector
Bakken/Three Forks
Eagle Ford
Permian Basin
Woodford & Other Mid-Continent – SCOOP/STACK
Marcellus/Utica
Niobrara
Gulf of Mexico/Offshore
Haynesville
Pinedale – Jonah Field – Uinta Basin
Enhanced Oil Recovery
Canadian E&Ps
International E&Ps
Oilfield Service Companies
Midstream
Mineral, Royalty, Infrastructure Holders, Acquisition Companies
Private Companies – E&Ps, Midstream, Energy Data and Technology Providers, Energy Capital, Government Energy Agencies
A work-in-progress schedule of the 2018 presenting companies is posted on the conference website and will be regularly updated.
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, 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 2017, EnerCom managed more than 2,100 one-on-one meeting requests. Buyside investors may request meetings on the conference website or contact EnerCom for more information at 303-296-8834.
How to Register: Investment professionals and oil and gas companies can 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; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; SMBC; Opportune LLP; Petrie Partners; and SunTrust Robinson Humphrey.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, 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 upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Feb. 27-28, 2019
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 RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.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 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 AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
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 Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
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 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.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
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.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE.
We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
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 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 Wells Fargo & Company
Wells Fargo & Company 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.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.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 Opportune LLP
Founded in 2005, Opportune is a leading global energy consulting firm specializing in adding value to clients across the energy industry, including upstream, midstream, downstream, power and gas, commodities trading and oilfield services.
Since we are not an audit firm, we are advocates of our clients and are not subject to the restrictions placed on other firms by regulatory bodies. Using our extensive knowledge of all sectors of the energy industry, we work with clients to provide comprehensive solutions to their operational and financial challenges.
Our practice areas include complex financial reporting, dispute resolution, enterprise risk, outsourcing, process and technology, reserve engineering and geosciences, restructuring, strategy and organization, tax, transactional due diligence and valuation. Opportune LLP is not a CPA firm.
Opportune's corporate headquarters are in Houston, Texas. The firm also has offices in Dallas, Denver, New York City, Tulsa, and the UK. For more information please call Ashley Hunt, Marketing Coordinator,
713.490.5050 and visit the web site https://opportune.com/.
About Petrie Partners, LLC
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.
The firm was formed in 2011 (as Strategic Energy Advisors) by senior bankers formerly with Bank of America Merrill Lynch and Petrie Parkman & Co., an investment bank that built a reputation as a most trusted advisor to energy clients during the nearly two decades leading up to its merger into Merrill Lynch in 2006.
Through tenure with Petrie Parkman, Merrill Lynch and Bank of America Merrill Lynch, the senior members of the Petrie team bring to bear an average of more than 25 years of energy investment banking experience, including over 300 energy M&A and capital raising transactions representing over $350 billion of aggregate consideration.
For information about the firm, please visit www.petrie.com or call the firm's Denver office (303.953.6768) or the Houston office (713.659.0760).
About SunTrust Robinson Humphrey
SunTrust Robinson Humphrey (STRH) is a leading, full-service corporate and investment bank dedicated to helping you successfully manage and grow your company through a comprehensive range of strategic advisory, capital raising, risk management, financing and investment solutions. We also offer a complete array of sales, trading and research services in both fixed income and equity.
Our firm's history dates back to 1894, and through the years we have built a reputation for delivering superior client service and in-depth market and industry expertise. At STRH, we are committed to your success. Our team of experienced professionals works closely with you to understand your unique needs and goals to provide sound, unbiased guidance that draws from the significant resources from across our entire universal banking platform. This collaborative One Team approach is focused solely on partnering with you to secure meaningful value throughout the life cycle of your company.
Our Energy & Power Investment Banking Group provides corporate and investment banking services to domestically headquartered companies in the energy and power sectors. We partner with our clients across the energy value chain to deliver full-service strategic advisory and financing solutions.
For more information please visit https://www.suntrustrh.com/industry-coverage/energy-power .
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SOURCE EnerCom, Inc.
DENVER, June 20, 2018 /PRNewswire/ -- EnerCom, Inc. is pleased to update the list of oil and gas companies and energy sector experts who will be presenters at the 23rd annual edition of The Oil & Gas Conference®, coming August 19-22, 2018, to the Westin Denver Downtown.
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations spanning 40 countries and six continents, including all U.S. shale basins, the Gulf of Mexico, Canada, Latin America and Africa. A work-in-progress list of the 2018 presenting companies will be posted and updated on the conference website.
The EnerCom Denver 2018 presenting companies include but are not limited to:
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, 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 2017, EnerCom managed more than 2,100 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can 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; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; and SMBC.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, 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 upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Feb. 27-28, 2019
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 RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.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 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 AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
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 Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
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 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.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
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.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE. We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
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 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 Wells Fargo & Company
Wells Fargo & Company 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.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.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/
CONTACT: 303-296-8834
View original content:http://www.prnewswire.com/news-releases/enercom-announces-presenting-companies-for-the-oil--gas-conference-23-300669633.html
SOURCE EnerCom, Inc.
DENVER, June 13, 2018 /PRNewswire/ -- EnerCom, Inc. is pleased to update the list of oil and gas companies and energy sector experts who will be presenters at the 23rd annual edition of The Oil & Gas Conference®, coming August 19-22, 2018, to the Westin Denver Downtown.
Public and Private Company Presenters: The 2018 edition of EnerCom's The Oil & Gas Conference® will feature public and private oil and gas companies with operations spanning 40 countries and six continents, including all U.S. shale basins, the Gulf of Mexico, Canada, Latin America and Africa. A work-in-progress list of the 2018 presenting companies will be posted and updated on the conference website.
The EnerCom Denver 2018 presenting companies include but are not limited to:
Who Attends the Conference: More than 2,000 institutional, private equity and hedge fund investors, 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 2017, EnerCom managed more than 2,100 one-on-one meeting requests.
How to Register: Investment professionals and oil and gas companies can 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; RS Energy Group; Moss Adams; and Preng & Associates. Sponsors of The Oil & Gas Conference® 23 are Bank of America Merrill Lynch; AssuredPartners; DNB Bank ASA; Fifth Third Bank; CIBC; Haynes and Boone; Credit Agricole CIB; Natixis; PJ SOLOMON; PNC Financial Services Group; Wells Fargo; MUFG; and SMBC.
About EnerCom, Inc.
Since 1994 EnerCom, Inc. has developed into a nationally recognized oil and gas-focused investor relations consultancy advising oil and gas industry clients on corporate strategy, asset valuations, investor communications, media relations and providing visual communications design.
EnerCom offers services and produces and publishes numerous data products and external communications tools for public and private energy companies including:
EnerCom's professionals have more than 170 years of industry and business experience and a proven track record of success.
Headquartered in Denver, with senior consultants in Dallas and Houston, 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 upcoming oil and gas investment conferences include:
EnerCom Denver (The Oil & Gas Conference®) – August 19-22, 2018
EnerCom Dallas – Feb. 27-28, 2019
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 RS Energy Group
RS Energy Group (RSEG) provides data-driven intelligence: evaluate assets, weigh valuable M&A opportunities and benchmark your business for more precise decision-making.
RSEG officially released its data solution in April 2017. RS Data™ provides clients with corrected, multi-sourced permit, completion and production data of unparalleled completeness and quality.
Today, RSEG's intelligence covers more than 150 companies operating in every key North American and many international energy plays with a powerful combination of practical insights at the asset level and a long-standing participation in capital markets. RSEG's independent, unbiased and accurate analysis forms a foundation of trust with its clients. Its collaborative approach, both internally and as an extension of its clients' research efforts, promotes innovation and fosters intimate, long term partnerships.
RS Energy Group (RSEG) is headquartered in Calgary, Alberta, with strategic locations in Houston, New York City, Philadelphia, San Francisco and Los Angeles. Contact RS Energy Group by phone at (403) 294-9111, or email info@rseg.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 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 AssuredPartners
AssuredPartners Colorado (AP CO) combines 30+ years of experience with leading-edge products to provide exceptional service and value to our customers. We provide a full range of brokerage services including employee benefits, property and casualty, and retirement. Headquartered in Colorado, we think globally but act locally, with personal services designed specifically for each individual client. AP CO utilizes resources with national networks of brokers to ensure we can meet your every need and find answers to your questions quickly and efficiently.
Our goal is to achieve a long-term relationship focused on bringing value to your employee benefits management and insurance programs. We are committed to utilizing our collective talent to support your insurance goals. We work to identify activities that drive claim frequency, and implement an action plan to control health care costs and promote a healthy work environment for your employees.
Securing the best insurance package for your business begins with planning. Analyzing all your risks is critical to successful implementation of your insurance plan. AP CO will partner with you by providing ongoing assistance, consultation and service that will help you control your insurance expenses, choose the best plan to fit your company's needs and promote health care consumerism.
For more information on Assured Partners, please visit the website, call (800) 322-9773 or email info@assuredptrco.com.
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 Fifth Third Bancorp
Fifth Third Bank is a diversified financial services company with over $120 billion in assets. The Bank's energy group is comprised of experienced and knowledgeable individuals that can assist in providing and structuring financial solutions to meet their clients' needs across the upstream, midstream, downstream and services sectors. Solutions and capabilities include commodity hedging, interest rate management, foreign exchange, debt capital markets, treasury management, and depository/investment products.
For more information, please contact Richard Butler at 713-401-6101 or richard.butler@53.com.
About CIBC
CIBC is a leading North American bank headquartered in Canada and with offices around the world. CIBC was originally founded nearly 150 years ago, and has supported and financed the energy industry for many decades. CIBC was recently ranked as the strongest publicly traded bank in North America by Bloomberg, and is rated A+/Aa3 by S&P and Moody's, respectively.
Our energy specialists draw on the breadth of CIBC's capabilities to provide market insights and creative solutions for our clients. Services include corporate banking, commodity and interest rate hedging and strategy, A&D advisory, and capital markets.
CIBC is publicly traded on the NYSE and Toronto Stock Exchange under the symbol "CM" and has a market cap of $36 billion and nearly $400 billion in total assets. For more information, please visit the CIBC energy website.
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 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.
The Bank provides support to clients in large international markets through its network, with a presence in major countries in Europe, the Americas, Asia and the Middle East.
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.
About Natixis
Natixis is the international corporate and investment banking, asset management, insurance and financial services arm of Groupe BPCE, the second-largest banking group in France.
Natixis Corporate & Investment Banking advises and assists corporations, financial institutions, institutional investors, financial sponsors, public-sector organizations and the networks of Groupe BPCE.
We furnish a diversified array of financing solutions, provide access to capital markets and transaction banking services.
Areas of expertise include Advisory: M&A, primary equity, capital & rating advisory; Financing: vanilla and structured; Capital Markets: equities, fixed income, credit, forex and commodities; Global Transaction Banking: trade finance, cash management, liquidity management and correspondent banking; Research: economic, credit, equity and quantitative.
The Bank leverages the expertise and highly technical skills of its teams, and provides industry-recognized research to build innovative and mix-and-matchable solutions. Corporate and Investment Banking is present on the main financial markets via three international platforms: Americas, Asia-Pacific, and EMEA (Europe, Middle East, Africa).
About PJ SOLOMON
PJ SOLOMON is an investment banking advisory firm that provides strategic advisory services to chief executive officers and senior management, owners of public and private companies, boards of directors, and special committees.
Our full suite of advisory services includes Mergers and Acquisitions, Restructuring and Capital Markets across a range of industry verticals.
The PJ SOLOMON Energy Advisory Group provides strategic investment banking advisory services to public and private clients across the energy chain. Drawing upon our extensive sector relationships and deep strategic and operational expertise, we can offer a unique and valued advisory platform for the upstream, upstream A&D, midstream and the utility sectors.
Based in our Houston office, the PJ SOLOMON Energy team holds more than 100 years of experience on a broad range of domestic and cross-border transactions including mergers and acquisitions, A&D, restructurings, bankruptcies, and public and private capital raisings.
Industry sectors/sub-sectors include: Upstream, Upstream A&D, Midstream, Energy related and Utilities.
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 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 Wells Fargo & Company
Wells Fargo & Company 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.
To learn more about Wells Fargo & Company, please visit the company's web site at www.wellsfargo.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/
View original content:http://www.prnewswire.com/news-releases/enercom-updates-list-of-presenters-for-the-oil--gas-conference-23-300665469.html
SOURCE EnerCom, Inc.
(TSX: AAV, NYSE: AAV)
CALGARY, May 29, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage") is pleased to announce that on May 29, 2018 it held its annual general and special meeting of shareholders (the "Meeting"). A total of 161,059,835 common shares (approximately 86.50% of the outstanding common shares) were represented at the Meeting in person or by proxy.
At the Meeting, shareholders approved the election of six nominees as directors of Advantage to serve until the next annual meeting of shareholders or until their successors are elected or appointed, with the number and percentage of common shares represented at the Meeting voting by way of ballot in favour or withheld from voting for the individual nominees as follows:
FOR |
WITHHELD | ||||||
Number |
Percentage |
Number |
Percentage | ||||
Jill T. Angevine |
148,550,991 |
97.88% |
3,211,542 |
2.12% | |||
Stephen E. Balog |
149,098,287 |
98.24% |
2,664,246 |
1.76% | |||
Grant B. Fagerheim |
149,078,117 |
98.23% |
2,684,416 |
1.77% | |||
Paul G. Haggis |
149,074,435 |
98.23% |
2,688,098 |
1.77% | |||
Andy J. Mah |
150,589,340 |
99.23% |
1,173,193 |
0.77% | |||
Ronald A. McIntosh |
148,462,811 |
97.83% |
3,299,722 |
2.17% |
For complete voting results, please see our Report of Voting Results available on SEDAR at www.sedar.com.
View original content:http://www.prnewswire.com/news-releases/advantage-announces-annual-meeting-voting-results-on-election-of-directors-300656052.html
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, May 8, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage") is pleased to announce that it has extended the expiry of its previously disclosed odd-lot share repurchase program (the "Odd Lot Program") by six weeks to June 19, 2018. Pursuant to the Odd Lot Program, Advantage has offered to buy back common shares from registered and beneficial shareholders of Advantage who own 99 or fewer common shares ("Odd Lot Holders"). The Odd Lot Program affords Odd Lot Holders the opportunity to sell all, but not less than all, of their common shares or to continue to maintain their current holdings. Advantage will purchase up to a maximum of Cdn. $4 million of its common shares under the Odd Lot Program (the "Maximum"). The Odd Lot Program is open to Odd Lot Holders of record as of March 20, 2018 and began on March 27, 2018. The Odd Lot Program will now expire once the Maximum is met or at the close of business on June 19, 2018, whichever comes earlier.
Odd Lot Holders may participate in the Odd Lot Program using the participation documents that were previously mailed to them. Questions regarding the Odd Lot Program should be directed to Computershare Investor Services Inc. toll free at 1-800-564-6253.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, Advantage's conduct of the Odd Lot Program and the details of the Odd Lot Program. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; risk that a significant number of Odd Lot Holders do not tender to the Odd Lot Program; failure of Advantage to achieve the perceived benefits of the Odd Lot Program; and changes in tax laws. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are cautioned that the foregoing lists of factors is not exhaustive.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; timing and amount of capital expenditures; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; and current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated.
These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
View original content:http://www.prnewswire.com/news-releases/advantage-extends-odd-lot-share-repurchase-program-300644137.html
SOURCE Advantage Oil & Gas Ltd.
Solid Cash Flow, Strong Well Results and Glacier Gas Plant Expansion Advances Liquids Development Strategy
(TSX: AAV, NYSE: AAV)
CALGARY, May 3, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report strong cash flow of $48.9 million ($0.26/share) and net income of $10.1 million ($0.05/share) during the first quarter of 2018. Cash flow was supported by the Corporation's proactive marketing strategy which included $18.1 million from hedging gains and enhanced netbacks from natural gas sales at Dawn, Ontario. In addition, liquids revenue increased 18% to $6.6 million and the Corporation achieved low total corporate cash costs of $1.13/mcfe ($6.78/boe) contributing to solid cash flow results. On April 30, 2018, the Corporation renewed its annual credit facility of $400 million with improved borrowing terms and maintained a strong balance sheet with a total debt to trailing 12 month cash flow ratio of 1.4.
First quarter results also included completion of six liquids rich wells on a new west Glacier well pad which demonstrated an 86% improvement in productivity over all previous Middle Montney Glacier wells. These six wells had a combined initial production flowrate of 64 mmcf/d and 1,914 bbls/d of C3+ liquids at the end of the first 48 hours. Two additional Lower Montney wells, located on the same well pad, had a combined production rate of 25.8 mmcf/d at the end of 37 hours of flow, which ranks in the top quartile of all Glacier wells. The Middle Montney wells will be brought on-production during the second half of 2018 after the Glacier plant expansion project is completed. In addition, liquids production from a four well pad at Valhalla, will be increased after completion of the Glacier plant expansion and flow unrestricted once the new Valhalla compressor and liquids handling facility is completed in the fourth quarter of 2018. This four well pad was completed prior to year-end 2017 and demonstrated an initial combined liquids productivity of 1,075 bbls/d.
Construction activity associated with the expansion of our 100% owned Glacier gas plant neared completion during the end of the first quarter when planned shut-downs commenced to tie-in new equipment. Average production during the quarter was 239 mmcfe/d (39,848 boe/d) and included two days of outage during the last week of March. As previously noted in Advantage's press release of April 19, 2018, this planned outage extended longer than scheduled in April due to a process upset which has been fully resolved. The Glacier plant expansion increases gas processing capacity from 250 to 400 mmcf/d and increases shallow cut propane plus ("C3+") liquids extraction capacity to 6,800 bbls/d providing room to accommodate future liquids production growth from east Glacier, Valhalla and Wembley. The Corporation's first quarter capital expenditures were $77.6 million, including $42 million invested in facilities infrastructure to support longer term liquids and natural gas development.
As previously announced, Advantage will lower natural gas production in 2018 in response to low price periods and to preserve dry gas productivity for higher price periods. Dry gas well completions in the second half of 2018 will be deferred to increase liquids rich drilling at east Glacier and Valhalla. The Corporation's first quarter liquids production of 1,105 bbls/d represents 3% of total production and generated 11% of total revenues. In 2019, Advantage targets to increase liquids production to 8% or more of total production and 13% or more of total production in 2020 which is anticipated to significantly enhance our netbacks and cash flows. Liquids production growth in 2018 and 2019 will primarily come from east Glacier and Valhalla, with significant growth from Wembley expected by mid-2020 when additional processing and pipeline capacity is expected to be completed.
As a result of increased liquids production, an active hedging program and secured egress to downstream markets in eastern Canada and the U.S. Midwest, Advantage has diversified its revenue portfolio reducing AECO gas exposure to approximately 27% of total revenues through 2019. Furthermore, Advantage continues to evaluate new commercial opportunities capable of providing incremental sources of long term natural gas demand and continued revenue diversification.
Operations Update
Glacier
Advantage completed an eight well pad located in the western portion of Glacier during the quarter. These wells were drilled in the second half of 2017 and consist of six wells in the Middle Montney and two wells in the Lower Montney.
The six Middle Montney wells further delineated all three layers within the Middle Montney and demonstrated a total combined production rate of 64 mmcf/d with an average rate of 10.6 mmcf/d per well at an average flowing pressure of 15,444 kPa at the end of 48 hours of flow. This represents an increase in the average per well test rate and average flowing pressure of 86% and 126%, respectively, compared to all of our previously drilled Glacier Middle Montney wells. Based on measured gas compositions from the six wells with a combined gas rate of 64 mmcf/d, the recoverable C3+ liquid rates is estimated to be 1,914 bbls/d at an average liquids yield of 30 bbls/mmcf, consistent with the previous results in this area of Glacier. Average frac count was increased to 34 stages per well which represents a 76% increase over our previous Middle Montney wells.
The two Lower Montney wells were flowed at an average rate of 12.9 mmcf/d per well at an average flowing pressure of 11,678 kPa at the end of 37 hours of flow. These results are consistent with the exceptional Lower Montney results that have been achieved in the western portion of Glacier over the past number of drilling programs.
During the first quarter of 2018, Advantage drilled a horizontal acid gas disposal well at Glacier to provide back-up and incremental disposal capacity to our two existing vertical disposal wells. This well was successfully drilled through our targeted interval with a lateral length of 1,585 meters and will be completed during the summer of 2018. Advantage's two existing vertical acid gas disposal wells are capable of handling the total acid gas stream based on current H2S compositions at Glacier and the expanded gas plant capacity of 400 mmcf/d. The new horizontal acid gas disposal well will provide additional acid gas disposal capacity to accommodate higher H2S gas levels as liquids development continues at Valhalla, Wembley and Progress.
Valhalla
Installation of Advantage's first compressor and liquids handling facility at Valhalla is continuing on track. This facility is designed to handle 40 mmcf/d of raw gas and 2,000 bbls/d of liquids and is expandable to accommodate future liquids rich production growth at Valhalla. Current Valhalla production has been limited due to the size of the existing Advantage pipeline connected to the Glacier gas plant. The Valhalla facility will help alleviate the current capacity limitation and is designed to separate wellhead liquids and transport liquids rich gas to Glacier for further processing and liquids extraction. Engineering design has been completed with the majority of major equipment items to be sourced from surplus equipment resulting from the Glacier gas plant expansion project. Construction is planned during the second half of 2018 with the facility scheduled to be brought-on stream in the fourth quarter of 2018.
Wembley
Engineering evaluations are underway to assess facility designs and pipeline options for transporting and processing liquids rich natural gas production from our Wembley land block. Prolific development of this liquids rich area has resulted in limited processing capacity. Options currently under consideration include transporting production back to our Glacier gas plant for processing and collaborating with third party processors and area producers to maximize efficiencies. Advantage is in the process of working through stakeholder consultations in anticipation of securing regulatory approvals targeted for 2019. Facility and pipeline construction is expected to occur during the first half of 2020; although, Advantage will be prepared to commence this work earlier if the timeline can be shortened.
Looking Forward
Our 2018 production guidance was updated recently to incorporate our strategy to lower natural gas production in response to low AECO price periods and the extended Glacier plant outage which occurred in the second quarter (refer to Advantage's press release dated April 19, 2018). Production for the second quarter of 2018 is expected to be 205 to 215 mmcfe/d, including liquids production between 950 and 1,150 bbls/d with higher per unit total corporate cash costs of $1.35/mcfe to $1.45/mcfe due to lower production. Annual 2018 production is estimated to average between 240 and 255 mcfe/d with average liquids production of approximately 1,800 bbls/d and a year-end exit rate of 2,400 bbls/d. Annual total corporate cash costs are estimated to be $1.10/mcfe to $1.30/mcfe. Advantage's 2018 capital program of $175 million is expected to be approximately 60% invested during the first half of the year.
Advantage has successfully executed on its Montney development at Glacier since 2008, achieving an industry leading low-cost structure, preserving a strong balance sheet and maintaining operational and financial flexibility. This solid foundation which includes a significant liquids resource on our 200 net sections of Montney lands provides flexibility to create long term value through multiple investment options as we respond promptly and responsibly to market conditions. We look forward to reporting on our progress through the remainder of 2018.
First Quarter 2018 Operating and Financial Summary
Three months ended | ||||||
Financial and Operating Highlights |
March 31 | |||||
2018 |
2017 | |||||
Financial ($000, except as otherwise indicated) |
||||||
Sales including realized hedging |
$ |
73,378 |
$ |
72,957 | ||
Net income and comprehensive income |
$ |
10,103 |
$ |
42,249 | ||
per share(1) |
$ |
0.05 |
$ |
0.23 | ||
Funds from operations |
$ |
48,882 |
$ |
53,792 | ||
per share(1) |
$ |
0.26 |
$ |
0.29 | ||
Total capital expenditures |
$ |
77,636 |
$ |
53,791 | ||
Working capital deficit(2) |
$ |
13,779 |
$ |
10,895 | ||
Bank indebtedness |
$ |
237,319 |
$ |
147,781 | ||
Basic weighted average shares (000) |
185,963 |
184,842 | ||||
Operating |
||||||
Daily Production |
||||||
Natural gas (mcf/d) |
232,456 |
230,906 | ||||
Liquids (bbls/d) |
1,105 |
1,151 | ||||
Total mcfe/d(3) |
239,086 |
237,812 | ||||
Total boe/d(3) |
39,848 |
39,635 | ||||
Average prices (including hedging) |
||||||
Natural gas ($/mcf) |
$ |
3.19 |
$ |
3.24 | ||
Liquids ($/bbl) |
$ |
66.11 |
$ |
53.73 | ||
Cash netbacks ($/mcfe)(3) |
||||||
Natural gas and liquids sales |
$ |
2.70 |
$ |
3.17 | ||
Realized gains on derivatives |
0.71 |
0.24 | ||||
Royalty expense |
(0.06) |
(0.10) | ||||
Operating expense |
(0.32) |
(0.23) | ||||
Transportation expense |
(0.57) |
(0.38) | ||||
Operating netback |
2.46 |
2.70 | ||||
General and administrative |
(0.08) |
(0.10) | ||||
Finance expense |
(0.10) |
(0.08) | ||||
Cash netbacks |
$ |
2.28 |
$ |
2.52 | ||
(1) |
Based on basic weighted average shares outstanding. |
(2) |
Working capital deficit includes cash and cash equivalents, trade and other receivables, prepaid expenses and deposits and trade and other accrued liabilities. |
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of liquids. |
The Corporation's unaudited interim condensed consolidated financial statements for the three months ended March 31, 2018 together with the notes thereto, and Management's Discussion and Analysis for the three months ended March 31, 2018 have been filed on SEDAR and with the SEC and are available on the Corporation's website at http://www.advantageog.com/investors/financial-reports/financial-reports-2018.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, completion of expansion of the Corporation's Glacier gas plant, including the anticipated raw processing capacity and shallow cut propane plus liquids extraction capacity following such expansion; Advantage's expectation that the expansion of the Corporation's Glacier gas plant will support anticipated production growth; the Corporation's plans to lower natural gas production and defer dry gas well completions; Advantage's targeted increase in liquids production for 2019 and 2020 and the expected effect of such production on netbacks and cash flows; the anticipated source of liquids production growth in 2018, 2019 and 2020 and the effect of such increased liquids production on the Corporation's revenue portfolio and AECO exposure; estimated recoverable C3+ liquid rates, combined gas rates and average C3+ liquids yields from certain wells at Glacier; anticipated timing of completion of a horizontal acid gas disposal well at Glacier, and the effect of such well on additional acid gas disposal capacity; the status of Advantage's first compressor and liquids handling facility at Valhalla, including expected gas and liquids handling capacity, the effect of such facility on current capacity limitations, and the targeted timing of construction and completion of such facility; options under consideration for transporting and processing production at Wembley, including the anticipated timing of securing regulatory approvals and commencing facilities and pipeline construction; Advantage's anticipated annual 2018 production guidance range, including expected total production and liquids production for the second quarter of 2018, expected amount of total production and liquids production for 2018 and expected exit liquids production; Advantage's capital program for 2018, including the expected timing of incurring capital expenditures; the factors that Advantage believes will provide Advantage with the ability to respond promptly and responsibly to market conditions; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; failure to achieve production targets on timelines anticipated or at all; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; individual well productivity; lack of available capacity on pipelines; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; delays in completion of the facility at Valhalla; delays in construction and completion of other infrastructure projects; that test results are not indicative of future production rates; lack of available capacity on pipelines; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form dated March 5, 2018, which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: timing of regulatory approvals; conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; well costs; expected annual production growth rates; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2018 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2018 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains a number of oil and gas metrics, including operating netbacks, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes.
References in this press release to flow rates and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include operating netbacks, cash netbacks, cash costs and total debt to annualized cash flow ratio. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
The following abbreviations used in this press release have the meanings set forth below. |
|
bbls/d |
barrels per day |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
GJ/d |
gigajoules per day |
mboe |
thousand barrels of oil equivalent |
mcf |
thousand cubic feet |
mcf/d |
thousand cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mcfe/d |
thousand cubic feet equivalent per day on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf/d |
million cubic feet per day |
mmcfe/d |
million cubic feet equivalent per day |
View original content:http://www.prnewswire.com/news-releases/advantage-announces-first-quarter-2018-operating--financial-results-300642670.html
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, April 19, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") advises that as previously disclosed in our press release dated March 5, 2018, a production outage was scheduled at our 100% owned Glacier gas plant in April 2018 associated with expanding our plant capacity to 400 mmcf/d and 6,800 bbls/d of liquids. This outage was scheduled to coincide with planned third party pipeline maintenance when AECO natural gas prices were anticipated to be negatively impacted. During plant start-up operations, Advantage experienced an upset in our gas dehydration process that has been fully resolved but required a longer outage than originally scheduled. Additional work is still required to complete the Glacier gas plant expansion project and we expect to have the expanded plant fully commissioned during the second quarter as originally planned.
With our increased focus on liquids rich development and in response to periods of low natural gas prices and netbacks in 2018, Advantage prudently decided to moderate the ramp up of gas production subsequent to the outage and may restrict natural gas production levels from time to time. Advantage will also defer dry gas well completions and re-allocate budgeted capital in support of drilling additional liquids rich wells at Valhalla and in the liquids rich Middle Montney formation at east Glacier during the second half of 2018. This will help preserve gas well productivity for the latter part of 2018 and beyond as lower storage levels and western Canadian basin supply declines could result in strengthening gas prices at which time, Advantage retains significant operational flexibility to immediately increase gas production.
This investment and production strategy is supported by our recent liquids rich drilling successes at Glacier and at our nearby land blocks at Valhalla and Wembley which extended and increased our significant inventory of liquids rich and dry gas drilling locations. Annual average liquids production is expected to grow by approximately 50% year on year to 1,800 bbls/d with a 2018 exit rate of approximately 2,400 bbls/d. Increased drilling on our liquids rich lands will support doubling Advantage's liquids production to 8% or more of total production during the latter part of 2019 and could potentially reach 13% or more in 2020. This program will significantly enhance our cash flow and netbacks.
Guidance Updated
Advantage's second quarter 2018 production is estimated to be within the range of 205 to 215 mmcfe/d, lower than earlier estimates. Total per unit corporate cash costs will be higher during the second quarter at $1.35/mcfe to $1.45/mcfe due to lower production and are expected to decrease to approximately $1.15/mcfe as production is increased during the second half of 2018.
The Corporation's 2018 annual guidance is updated as follows:
Updated |
Previous | ||||
Average Annual Production |
(mmcfe/d) |
240 to 255 |
255 to 265 | ||
(boe/d) |
(40,000 to 42,500) |
(42,500 to 44,170) | |||
Annual average liquids production (bbls/d) |
1,800 |
1,900 | |||
Exit liquids production (bbls/d) |
2,400 |
2,400 | |||
Royalties (%) |
3% to 5% |
3% to 5% | |||
Operating costs ($/mcfe) |
$0.28 to $0.33 |
$0.25 to $0.29 | |||
Transportation costs ($/mcfe) |
$0.55 to $0.62 |
$0.52 to $0.58 | |||
Total corporate cash costs ($/mcfe) |
$1.10 to $1.30 |
$1.00 to $1.20 | |||
Capital Expenditures |
$175 million |
$175 million |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, expected timing of completion of the Glacier gas plant expansion project; potential restriction on natural gas production levels; the deferral of well completions and the re-allocation of capital to drill new wells at Glacier and the timing and anticipated benefits therefrom; the anticipated number of wells to be drilled; the Corporation's expectation that liquids production for 2018 will grow and the 2018 year end exit rate; the impact of increased drilling on the Corporation's total production during the latter part of 2019 and 2020 and the benefits to be derived therefrom; anticipated annual 2018 production and financial guidance; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; Advantage's success at acquisition, exploitation and development of reserves; failure to achieve production targets on timelines anticipated or at all; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; individual well productivity; lack of available capacity on pipelines; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; delays in gas production from the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form dated March 5, 2018 which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: timing of regulatory approvals, conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; well costs; expected annual production growth rate; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2018 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2018 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release and, in particular the information in respect of the Corporation's prospective annual operating costs, transportation costs, total corporate cash costs and capital expenditures may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions, including the assumptions discussed above, and assumptions with respect to the costs and expenditures to be incurred by the Corporation, capital equipment and operating costs, foreign exchange rates, taxation rates for the Corporation, general and administrative expenses and the prices to be paid for the Corporation's production. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the FOFI or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. However, because this information is highly subjective and subject to numerous risks including the risks discussed above, it should not be relied on as necessarily indicative of future results. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The following abbreviations used in this press release have the meanings set forth below.
bbls/d |
barrels per day |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf/d |
million cubic feet per day |
mmcfe/d |
million cubic feet equivalent per day |
View original content:http://www.prnewswire.com/news-releases/advantage-announces-glacier-gas-plant-expansion-update-lowering-natural-gas-production--increasing-liquids-rich-drilling-300633492.html
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, April 15, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to announce the appointment of David Sterna to the position of Vice President Marketing and Commercial. Mr. Sterna has significant expertise with commodity marketing including the development of market diversification initiatives such as LNG and industrial gas projects. He has over 20 years of executive and senior Management experience and was most recently at Progress Energy Canada Ltd., a wholly owned subsidiary of Petroliam Nasional Berhad (PETRONAS), with previous positions at a number of senior and intermediate upstream oil and gas producers.
Advantage believes that increasing global and domestic demand for clean natural gas and associated by-products will create long term Canadian supply growth opportunities to new commercial ventures that could broaden and diversify the Corporation's revenue sources. Mr. Sterna's knowledge and experience in this new Executive position will complement Advantage's existing leadership team in the development/implementation of go-forward strategies to enhance the continued development of the Corporation's industry leading low cost Montney natural gas and liquids resource.
About Advantage
Advantage Oil & Gas Ltd. is a Canadian upstream exploration and production company focused on development of its significant position in the Montney natural gas and liquids resource play. The Corporation's common shares trade on the Toronto and New York Stock Exchanges under the symbol AAV.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, Advantage's belief that increasing global and domestic demand for clean natural gas and associated by-products provides long term opportunities to broaden revenue sources and to supply future projects. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations and changes in tax laws. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are cautioned that the foregoing lists of factors is not exhaustive.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; timing and amount of capital expenditures; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; and current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated.
These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
View original content:http://www.prnewswire.com/news-releases/advantage-announces-executive-appointment-vice-president-marketing--commercial-300629877.html
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, March 21, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage") is commencing an odd-lot share repurchase program (the "Odd Lot Program") pursuant to which it will offer to buy back common shares from registered and beneficial shareholders of Advantage who own 99 or fewer common shares ("Odd Lot Holders"). The Odd Lot Program affords Odd Lot Holders the opportunity to sell all, but not less than all, of their common shares or to continue to maintain their current holdings. Advantage will purchase up to a maximum of Cdn. $4 million of its common shares under the Odd Lot Program (the "Maximum").
The Odd Lot Program will begin on March 27, 2018 and will expire once the Maximum is met or at the close of business on May 8, 2018 (the "Period"), unless otherwise extended. Advantage may extend the Period for up to an additional six weeks and may increase the Maximum at its sole discretion.
Under the Odd Lot Program, Advantage will pay tendering Odd Lot Holders the following:
Advantage believes that the Odd Lot Program will be beneficial to Odd Lot Holders as it is a voluntary program allowing tendering Odd Lot Holders to dispose of their common shares without incurring prohibitive brokerage and other fees. Further, if the Odd Lot Program is successful in significantly reducing the number of Odd Lot Holders, Advantage believes that both Advantage and its securityholders will benefit from the cost-savings respecting annual mailings and other securityholder communications as a result of a reduced number of shareholders.
The Odd Lot Program will be open to Odd Lot Holders of record as of March 20, 2018. Information about the Odd Lot Program and participation documents will be mailed to those Odd Lot Holders. Advantage has retained Computershare Investor Services Inc. ("Computershare") to manage the Odd Lot Program. Questions regarding the Odd Lot Program should be directed to Computershare toll free at 1-800-564-6253.
As of March 20, 2018, approximately 0.1% of the common shares are held by Odd Lot Holders. Any common shares purchased by Advantage under the Odd Lot Program will be cancelled.
This press release does not constitute an offer to sell, or the solicitation of an offer to buy, any securities in any jurisdiction. Advantage is not making any recommendation as it relates to holding or selling common shares, and is not making any representation as to the price which may be realized on the sale of common shares under the Odd Lot Program. Eligible Odd Lot Holders may wish to obtain advice from their broker or financial advisor as to the advisability of participating. The tax consequences for each Odd Lot Holder in the Odd Lot Program may vary. Advantage and Computershare make no representations with respect to the tax consequences for a particular Odd Lot Holder. It is recommended that each Odd Lot Holder consult their personal tax advisor as to the consequences to them of a sale under the Odd Lot Program. Participation in the Odd Lot Program is voluntary.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, Advantage's conduct of the Odd Lot Program, Advantage's beliefs regarding the benefits of the Odd Lot Program and the details of the Odd Lot Program. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; risk that a significant number of Odd Lot Holders do not tender to the Odd Lot Program; failure of Advantage to achieve the perceived benefits of the Odd Lot Program; and changes in tax laws. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are cautioned that the foregoing lists of factors is not exhaustive.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; timing and amount of capital expenditures; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; and current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated.
These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
SOURCE Advantage Oil & Gas Ltd.
Solid 2017 Operational Performance and Record Net Income, Successful First Wells at Wembley & Progress Confirm High Liquid Yields & Free Condensate
(TSX: AAV, NYSE: AAV)
CALGARY, March 5, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report record net income for 2017 of $95 million ($0.51/share) resulting from strong operating and financial results and drilling successes which now include our first liquids rich wells at Wembley and Progress, Alberta. Advantage's first delineation well at Wembley demonstrated a flow rate of 1,312 boe/d with 819 bbls/d of propane plus ("C3+") hydrocarbon liquids (yield of 277 bbls/mmcf) including wellhead condensate/oil of 624 bbls/d. Our first delineation well at Progress demonstrated a flow rate of 624 boe/d with 172 bbls/d of C3+ hydrocarbon liquids including 75 bbls/d of wellhead condensate/oil. These results and our 2017 liquids rich four well pad at Valhalla (combined flow rate of 6,410 boe/d with 1,075 bbls/d liquids) confirm significant hydrocarbon liquids and free condensate/oil accumulations within our 110 net sections (70,400 acres) of land contained in these three areas, located proximal to our Glacier property. These results help extend and confirm the Corporation's growing liquids rich inventory beyond the liquids rich Middle Montney formation at Glacier and allows Advantage to invest in additional resource opportunities to continue creating long term value.
We continue to demonstrate our passion and dedication in striving for operational, financial, health, safety and environmental excellence. We look forward to reporting results on our progress through 2018 and beyond as we maintain our commitment on operational excellence at our Glacier project while increasing our focus on liquids development and prudently undertake capital investments to grow shareholder value.
Operating and Financial Results Summary
(please refer to Advantage's press release on February 12, 2018 which provides year-end reserves and an operational update)
Key 2017 results which contributed to our strong earnings is included below:
Valhalla, Wembley and Progress Area Updates
As a result of our liquids rich drilling successes in these areas, plans are currently being reviewed to evaluate future drilling along with gathering and processing system infrastructure designs to; i) ensure future delineation/appraisal drilling is conducted in a manner that systematically obtains the most knowledge and to optimize returns on all multiple liquids rich Montney layers while preserving financial flexibility; ii) evaluate options to optimize future investment returns through integration of our land blocks into our 100% owned low cost processing and gathering infrastructure; and iii) evaluate innovative value chain concepts which could help mitigate commodity price volatility while maintaining attractive returns on investment.
We are excited about these initial results and observe that additional industry locations have recently been licensed and more wells have been drilled adjacent to our lands. Area producers are also evaluating additional Montney layers which further demonstrates the significant exposure to the liquids rich development potential that could be realized on Advantage's land blocks.
Wembley (31 net sections)
Advantage's first delineation well located at 12-25-72-08W6 was drilled to a lateral length of 2,254 meters and was fracture stimulated with 38 stages. The 12-25 well was production tested over a total of 17 days at restricted rates due to regulatory flaring limitations and was flowed up the production casing at a draw down of less than 20% of the reservoir pressure. At the conclusion of our production test period, our well demonstrated an average flow rate of 1,312 boe/d consisting of 2.9 mmcf/d of gas and 819 bbls/d of hydrocarbon liquids. The wellhead condensate/oil rate was 624 bbls/d with an additional 195 bbls/d of C3+ liquids based on a shallow cut extraction process. The condensate/oil is 84% of the total recoverable liquids. Consistent with industry offset Pipestone/Wembley wells during production testing and permanent production, the condensate/oil yield continued to increase as frac load water was being recovered. Only 34% of the initial load fluid in our 12-25 well has been recovered and we anticipate that liquid rates could continue to improve with longer production times and the installation of production tubing to optimize wellbore flow dynamics. Options for tie-in of the 12-25 well for permanent production, including connecting the well back to our Glacier gas plant, are being evaluated as near term processing capacity is limited in the immediate area.
Progress (39 net sections)
Our first delineation well located at 13-31-77-09W6 was drilled to a lateral length of 2,313 meters and was fracture stimulated with 44 stages. The 13-31 well was production tested over a 6 day period and was drawn down to less than 40% of the reservoir pressure while flowing up production casing. At the conclusion of the test, the 13-31 well was producing at an average rate of 624 boe/d consisting of 2.7 mmcf/d of gas and 172 bbls/d of hydrocarbon liquids. The wellhead condensate rate was 75 bbls/d with an additional 97 bbls/d of C3+ liquids based on a shallow cut extraction process. The condensate/oil is 63% of the total recoverable liquids. Consistent with the profile of producing industry offset wells, the flow rate of our 13-31 well increased throughout the flow period as frac load water was being recovered. Only 13% of the initial load fluid in our well has been recovered and we anticipate that the production rate could continue to improve with longer production times and installation of production tubing to optimize wellbore flow dynamics. Options for tie-in of the 13-31 well for permanent production, including connecting the well back to our Glacier gas plant, is being evaluated as near term processing capacity is limited in the immediate area.
Valhalla (40 net sections)
At Valhalla, design and permitting is underway to construct an initial facility installation which includes 40 mmcf/d of compression and liquids handling equipment to collect and transport natural gas and liquids for processing at our 100% owned Glacier gas plant. This facility is designed to accommodate liquids rich natural gas production from our recent four well pad and is expandable to accommodate additional growth. The location of this facility could also be utilized as a hub where future production from Wembley and Progress could be collected and transported to our Glacier gas plant such that netbacks and investment returns may be enhanced due to the benefits realized through economies of scale and integration with our established industry leading low cost structure. This facility is scheduled to be completed in the fourth quarter of 2018.
Glacier Gas Plant Expansion
The expansion of our 100% owned Glacier Gas Plant is on-track for anticipated completion in the second quarter of 2018. Two incremental process equipment units were added as part of the expansion project to begin generating new revenue and provide more flexibility and efficiency in the plant's operation due to successful wells in our adjacent land blocks. One of the process units added was an electric power generator which will provide surplus electricity sales (2.4 MW) into the Alberta grid and the other process unit is a heat exchanger. Upon completion, the Glacier gas plant will provide 400 mmcf/d of raw gas processing capability, including 6,800 bbls/d of C3+ liquids extraction and will provide additional capacity to accommodate future growth and process production from our adjacent land blocks.
Market Diversification
Advantage's continued market diversification initiatives are expected to result in revenue exposure to AECO prices of 4% and 28% for the first quarter and calendar year 2018, respectively. In addition to our Dawn, Ontario market exposure, which comprises approximately 20% of our current production, we have recently added contracts to transport natural gas to the Chicago/Ventura U.S. mid-west markets. This will start in November 2018 with an initial volume of 20,000 mmbtu/d and increases to an annual average volume of 35,000 mmbtu/d in 2019 and 62,500 mmbtu/d in 2020 at a cost of approximately US $1.15/mmbtu to US $1.20/mmbtu.
Complementing our physical market diversification efforts are other financial contracts whereby we have both fixed the price on a portion of our natural gas production and entered basis contracts to diversify revenue to the Henry Hub market. For 2018, we have fixed the price on 37% of our estimated natural gas production (91 mmcf/d) at Cdn $3.21/mcf and 46 mmcf/d for 2019 at Cdn $2.89/mcf. We also have 19 mmcf/d (approximately 8% of 2018 estimated production) and 25 mmcf/d of our 2019 natural gas production exposed to Henry Hub prices with basis differentials of US $ 0.95/mmbtu and US $ 0.90/mmbtu respectively.
Looking Forward
Our 2018 production guidance includes a slight reduction in production volumes during the second quarter of 2018 followed by a continued increase through the second half of 2018 to achieve our production guidance of 255 to 265 mmcfe/d. The first quarter is anticipated to be 242 to 246 mmcfe/d and approximately 3% lower in the second quarter of 2018 to accommodate a short plant outage in order to complete the integration of new equipment and commissioning as part of the Glacier gas plant expansion. Average liquids production for 2018 is targeted at 1,900 bbls/d, exiting the year at 2,400 bbls/d. Advantage's $175 million capital program for 2018 is weighted approximately 60% to the first half of the year, with the majority of spending occurring during the first quarter including completion of the Glacier Gas Plant expansion.
Advantage's Montney development at Glacier has been successfully executed since 2008 based on maintaining an industry leading low cost structure, preserving a strong balance sheet and preserving operational and financial flexibility. These factors, in conjunction with an increased focus on liquids development in 2018 and beyond will provide Advantage with the ability to respond promptly and responsibly to market conditions. We wish to thank all of our shareholders and our Board of Directors for their ongoing support and most importantly, all of our people
We look forward to reporting on our progress through 2018.
Fourth Quarter and Full-Year Operating and Financial Summary
Three months ended |
Year ended | |||||||||||
Financial and Operating Highlights |
December 31 |
December 31 | ||||||||||
2017 |
2016 |
2017 |
2016 | |||||||||
Financial ($000, except as otherwise indicated) |
||||||||||||
Sales including realized hedging |
$ |
65,779 |
$ |
71,090 |
$ |
259,611 |
$ |
215,027 | ||||
Funds from operations |
$ |
43,883 |
$ |
54,610 |
$ |
183,202 |
$ |
166,861 | ||||
per share(1) |
$ |
0.24 |
$ |
0.30 |
$ |
0.99 |
$ |
0.92 | ||||
Total capital expenditures |
$ |
73,723 |
$ |
30,043 |
$ |
248,774 |
$ |
128,014 | ||||
Working capital deficit(2) |
$ |
13,808 |
$ |
6,167 |
$ |
13,808 |
$ |
6,167 | ||||
Bank indebtedness |
$ |
208,978 |
$ |
153,102 |
$ |
208,978 |
$ |
153,102 | ||||
Basic weighted average shares (000) |
185,963 |
184,641 |
185,641 |
182,056 | ||||||||
Operating |
||||||||||||
Daily Production |
||||||||||||
Natural gas (mcf/d) |
237,780 |
215,369 |
228,583 |
197,852 | ||||||||
Liquids (bbls/d) |
1,227 |
949 |
1,218 |
915 | ||||||||
Total mcfe/d(3) |
245,142 |
221,063 |
235,891 |
203,342 | ||||||||
Total boe/d(3) |
40,857 |
36,844 |
39,315 |
33,890 | ||||||||
Average prices (including hedging) |
||||||||||||
Natural gas ($/mcf) |
$ |
2.69 |
$ |
3.35 |
$ |
2.82 |
$ |
2.75 | ||||
Liquids ($/bbl) |
$ |
60.48 |
$ |
53.01 |
$ |
54.28 |
$ |
47.97 | ||||
Cash netbacks ($/mcfe)(3) |
||||||||||||
Natural gas and liquids sales |
$ |
2.38 |
$ |
3.17 |
$ |
2.69 |
$ |
2.18 | ||||
Realized gains on derivatives |
0.53 |
0.32 |
0.32 |
0.71 | ||||||||
Royalty expense |
(0.07) |
(0.18) |
(0.07) |
(0.07) | ||||||||
Operating expense |
(0.26) |
(0.22) |
(0.25) |
(0.27) | ||||||||
Transportation expense(4) |
(0.50) |
(0.26) |
(0.40) |
(0.09) | ||||||||
Operating netback(1) |
2.08 |
2.83 |
2.29 |
2.46 | ||||||||
General and administrative |
(0.05) |
(0.08) |
(0.08) |
(0.10) | ||||||||
Finance expense |
(0.09) |
(0.09) |
(0.08) |
(0.13) | ||||||||
Other income |
- |
0.02 |
- |
0.01 | ||||||||
Cash netbacks(1) |
$ |
1.94 |
$ |
2.68 |
$ |
2.13 |
$ |
2.24 |
(1) |
Based on basic weighted average shares outstanding. | ||||||||
(2) |
Working capital deficit includes cash and cash equivalents, trade and other receivables, prepaid expenses and deposits and trade and other accrued liabilities. | ||||||||
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of liquids. | ||||||||
(4) |
Commencing on November 1, 2016, Advantage requested that its natural gas marketing contract be modified to reflect natural gas transportation as a cost. Prior to November 1, 2016, Advantage's realized natural gas prices were reduced for natural gas transportation from the sales points to AECO. This change has no effect on cash flow, cash netbacks, or net income; however, Advantage believes this is more instructive for our investors to compare cost structures going forward. |
Production increased 11% in the fourth quarter of 2017 to a record 245 mmcfe/d (40,857 boe/d) with 2017 average production higher by 16% to 236 mmcfe/d (39,315 boe/d), as compared to the same periods in 2016. Natural gas liquids production has grown to 1,227 bbls/d for the fourth quarter of 2017, a 29% increase from the same period in 2016 and consisting of approximately 70% condensate. Production met our original guidance targets despite significant third party pipeline restrictions which impacted the majority of western Canadian producers through 2017.
Funds from operations were $43.9 million or $0.24/share for the quarter and $183.2 million or $0.99/share for the year. Higher production, market diversification initiatives, a proactive hedging strategy and industry-leading low corporate cash costs of $0.88/mcfe for the year resulted in strong funds from operations.
Net income earned of $95.0 million or $0.51/share for the year and $21.4 million or $0.12/share for the fourth quarter of 2017. Higher production and gains on our derivative contracts resulted in net income throughout 2017. Excluding unrealized gains on derivatives of $17.2 million and $73.3 million in the three months and year ended December 31, 2017, Advantage would have still generated significant net income.
Achieved a 3 year all-in capital efficiency of $15,333/boe/d. Advantage's 2017 all-in capital efficiency of $17,000/boe/d includes $80 million for our Glacier gas plant expansion and $7 million for land acquisitions, which results in a capital efficiency of $11,100/boe/d when these expenditures are excluded.
Continued market diversification such that only 28% of our estimated 2018 revenue is exposed to AECO prices. This market diversification includes fixed price hedges, Henry Hub and Dawn market exposures and access to the Alliance Pipeline in 2018 which will provide further opportunities into the mid-west U.S.
The Corporation's audited consolidated financial statements for the fiscal year ended December 31, 2017 together with the notes thereto, and Management's Discussion and Analysis for the year ended December 31, 2017 have been filed on SEDAR and with the SEC and are available on the Corporation's website at http://www.advantageog.com/investors/financial-reports/2017-2. The Corporation's audited consolidated financial statements for the fiscal year ended December 31, 2016 are also available on the Corporation's website via the same webpage. Upon request, Advantage will provide a hard copy of any financial reports free of charge.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the Corporation's belief that recent well results help extend and confirm the Corporation's significant liquids rich inventory and strengthens Advantage's options to create long term value; the Corporation's plans to continue development of its oil and natural gas resource contained within its land holdings and increase production; the Corporation's plans to evaluate future drilling along with gathering and processing system infrastructure designs and Advantage's strategy with respect to such evaluation; Advantage's anticipation that its 12-25 and 13-31 wells could continue to improve with longer production times and installation of production tubing to optimize flow dynamics; options being considered by the Corporation for tie-in of the 12-25 and 13-31 wells for permanent production; expected timing of completion of the facility at Valhalla; expected timing of completion of expansion of the Corporation's Glacier gas plant, including the anticipated raw processing capacity following such expansion; Advantage's expectation that the expansion of the Corporation's Glacier gas plant will support anticipated production growth; Advantage's expected revenue exposure from its continued market diversification initiatives; Advantage's future hedging positions and the terms of the Corporation's derivative contracts; Advantage's anticipated annual 2018 production guidance range, including expected production in each of the first and second quarters of 2018 and the expected amount of liquids production for 2018 and exit liquids production; Advantage's capital program for 2018, including the expected timing of incurring capital expenditures; the factors that Advantage believes will provide Advantage with the ability to respond promptly and responsibly to market conditions; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; failure to achieve production targets on timelines anticipated or at all; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; individual well productivity; lack of available capacity on pipelines; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; delays in completion of the facility at Valhalla; that test results are not indicative of future production rates; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form dated March 5, 2018 which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: timing of regulatory approvals, conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; well costs; expected annual production growth rates availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2018 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2018 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains a number of oil and gas metrics, including operating netbacks, reserve additions, proved plus probable finding and development cost and proved developed producing F&D cost, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes. Operating netback is calculated by adding natural gas and liquids sales with realized gains and losses on derivatives and subtracting royalty expense, operating expense and transportation expense. Reserve replacement is calculated by dividing reserves net volume additions of 62,063 mboe for proved plus probable reserves and 65,355 mboe for proved reserves by the current annual production of 14,350 mboe and expressed as a percentage and using Sproule Associates Ltd. pricing at December 31, 2017. F&D costs are calculated by dividing total capital by reserve additions during the applicable period. Total capital includes both capital expenditures incurred and changes in future development capital required to bring proved undeveloped reserves and probable reserves to production during the applicable period. Reserve additions is calculated as the change in reserves from the beginning to the end of the applicable period excluding production. Sproule Associates Ltd. was engaged as an independent qualified reserve evaluator to evaluate Advantage's year-end reserves as of December 31, 2017 in accordance with National Instrument 51-101 and the Canadian Oil and Gas Evaluation Handbook. Information in respect of our reserves for the year ended December 31, 2017 is included in our Annual Information Form dated March 5, 2018 which is available at www.Sedar.com.
References in this press release to flow rates and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include operating netbacks, cash netbacks, cash costs, all-in capital efficiency and total debt to cash flow ratio. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period All-in capital efficiency is calculated by dividing year-end total capital development costs for oil and gas activities including drilling, completion, facilities, infrastructure, office and capitalized general and administrative costs (excluding abandonment and reclamation costs and acquisition and disposition related costs and proceeds) by the average production additions of the applicable year to replace base production declines and deliver production growth targets, expressed in $/boe/d. Production per debt-adjusted share is equal to the average production volumes for a year divided by the sum of the number of common shares issued and outstanding at year end and the net debt converted to equity at year end using the closing share price of Advantage on the TSX at year end. Three year annual average production growth per debt-adjusted share is the percentage change in production per debt-adjusted share from 2014 to 2017. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
The following abbreviations used in this press |
|
bbls/d |
barrels per day |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
GJ/d |
gigajoules per day |
mboe |
thousand barrels of oil equivalent |
mcf |
thousand cubic feet |
mcf/d |
thousand cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mcfe/d |
thousand cubic feet equivalent per day on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf/d |
million cubic feet per day |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
Low Cost Reserve Additions and Record
2017 Production & Operating Performance
(TSX: AAV, NYSE: AAV)
CALGARY, Feb. 12, 2018 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that the Corporation's 2017 Montney development program replaced 433% of annual production, generated low cost reserve additions in each reserve category and extended liquids rich reserve bookings beyond Glacier to our Valhalla land block. Reserve additions at Glacier were led by new location bookings in the liquids rich Middle Montney, prolific natural gas well results in the Lower Montney and positive technical revisions resulting from better long term producing well performance. At Valhalla, successful drilling results confirmed strong natural gas rates and high liquid yields in the Upper and Middle Montney formations. This resulted in Advantage's first bookings of undeveloped locations at Valhalla which has further increased our significant liquids rich drilling inventory.
Advantage achieved record fourth quarter production of 245 mmcfe/d (40,857 boe/d) and increased our annual production by 16% (14% per share) to a record 236 mmcfe/d (39,315 boe/d). Advantage's annual cash flow increased 10% to $183 million, supported by a 50% increase in liquids revenue and the Corporation's proactive market diversification and hedging initiatives. These initiatives resulted in a 16% exposure to AECO natural gas prices and an average realized natural gas price of $2.69/mcf as compared to an AECO daily price of $1.69/mcf in the fourth quarter. Furthermore, these initiatives are expected to result in the Corporation's 2018 revenue exposure to AECO prices of 4% and 28% for the first quarter and calendar 2018, respectively. The Corporation successfully reduced 2017 total cash costs to $0.88/mcfe including operating costs of $0.25/mcfe which helped contribute to a year-end total debt to cash flow ratio of 1.2.
Advantage's 2017 operating activities included liquids rich drilling successes, the acquisition of 37 sections of additional liquids rich Montney lands and the commencement of a major expansion of our 100% owned Glacier gas plant which further enhances our operational flexibility. These achievements position Advantage to increase its focus on liquids development in 2018 and beyond with the ability to respond promptly and responsibly to market conditions.
Highlights of our year-end reserve additions are:
Highlights of our operating and financial results in 2017 are:
2017 Reserves Related Commentary and Analysis
Sproule Associates Ltd. ("Sproule") was engaged as an independent qualified reserve evaluator to evaluate Advantage's year-end reserves as of December 31, 2017 ("Sproule 2017 reserve report") in accordance with National Instrument 51-101 ("NI 51-101") and the Canadian Oil and Gas Evaluation Handbook ("COGE Handbook"). Reserves are stated on a gross (before royalties) working interest basis unless otherwise indicated. Additional details are provided in the accompanying tables to this release and additional reserve information as required under NI 51-101 will be included in our Annual Information Form which will be filed on SEDAR on or before March 31, 2018. All references to 2017 operational and financial results are estimates only and have not been reviewed or audited by our independent auditor. Advantage is expected to release its fourth quarter and year-end results after markets close on March 5, 2018.
Advantage's 2017 reserve additions include contributions from Glacier and Valhalla. The Corporation's Valhalla land block is located approximately 16 kilometers east of Glacier and is pipeline connected to our 100% owned Glacier gas plant. In 2017, a 4 well Montney pad was drilled as a follow-up to 3 wells that were placed on production in 2016. This new 4 well pad demonstrated a combined initial production test rate of 6,410 boe/d comprised of 32 mmcf/d gas and 1,075 bbls/d of liquids (based on Glacier gas plant shallow cut extraction process). Individual well C3+ liquid yields of 20 bbls/mmcf to in-excess of 100 bbls/mmcf with free condensate and/or oil compositions of up to 90% were recovered. These wells will be placed on restricted production through the first half of 2018 due to the need to install additional liquids handling facilities at Valhalla. All wells are expected to be produced unrestricted when the new Valhalla compressor and liquids handling equipment is installed by the fourth quarter of 2018.
At Glacier, our activity was focused in the Lower and Middle Montney during 2017 and continued to demonstrate technology improvements in well operations and results. Advantage's eight well pad that was put on production in early 2017 included five Lower Montney wells which produced at rates of approximately 8 mmcf/d after more than a year of production. In the Middle Montney, several wells were drilled in previously undrilled areas of Glacier and proved up additional liquids rich reserves and demonstrated production rates above type curve expectations.
At our Wembley and Progress land blocks, one well at Progress and one well at Wembley have been fracture stimulated and flow results are expected to be available once production testing is completed.
Additional comments pertaining to each of the reserve categories are included below:
PDP reserves increased 27% due to the recognition of 27 new Glacier wells that were brought on production through 2017 and higher reserves assignments on historical producing wells due to stronger performance than previously forecast.
1P reserves increased 20% resulting from technical revisions which accounted for 45% of the 1P reserve additions. The remaining reserve additions resulted from the conversion of probable locations to the proved reserves category and the booking of new proven undeveloped locations.
2P reserves increased 13% through the addition of 56 new wells and locations (40 Glacier and 16 Valhalla). Of the 56 new wells and locations, 30 were proved undeveloped locations. A total of 337 undeveloped locations were booked in the 2017 reserve report. Management estimates in-excess of 1,200 total Montney locations remains undrilled at Glacier and Valhalla.
2P FDC increased by $62 million to $1.66 billion as the reduction in facilities capital expenditures in the reserve report were offset by the cost of booking additional future well locations.
The strong recycle ratios reinforces the benefit of Advantage's industry leading low cost structure which continues to support strong netbacks and profit margins. These recycle ratios included the Corporation's hedges and were achieved in the environment where the AECO daily natural gas price averaged Cdn $2.15/mcf in 2017.
Since Advantage's Montney development program began in 2008, 2P reserves have grown at an average compound annual growth rate ("CAGR") of 13% per year to 2.49 Tcfe (413.8 million boe) with a 2P and 1P reserve Net Present Value of $2.55 billion and $1.77 billion, respectively as at December 31, 2017 (10% discount factor on a pre-tax basis).
The Sproule 2017 reserve report demonstrates the continued efficient conversion of identified natural gas and natural gas liquids resources into 2P reserves. The reserves by category and year over year changes compared to 2016 are indicated below:
Reserve |
Conventional |
NGLs |
Total Gas |
% Change from |
PDP |
0.46 |
4.48 |
0.48 |
27% |
1P |
1.70 |
23.06 |
1.84 |
20% |
2P |
2.29 |
31.77 |
2.48 |
13% |
The total number of 2P future well locations booked and the 2P estimated ultimate recoverable ("EUR") conventional natural gas volumes per well assigned by Sproule in the Sproule 2017 reserve report are illustrated in the following table:
Sproule |
Sproule | ||
Developed |
Undeveloped |
Undeveloped | |
Upper |
115 |
138 |
5.9 |
Middle |
31 |
118 |
5.2 |
Lower |
51 |
81 |
6.5 |
Total |
197 |
337 |
Advantage's 1P reserve life index is 21 years and its 2P reserve life index is 28 years based on the Corporation's average fourth quarter 2017 production rate of approximately 245 mmcfe/d.
2017 Operating Results Summary
(References to 2017 operational and financial results are estimates only and have not been reviewed or audited by our independent auditor. Advantage is expected to release its fourth quarter and year-end results after markets close on March 5, 2018)
Key operational results during the fourth quarter of 2017 and for calendar 2017 are indicated below:
Q4 2017E |
2017E | |
Production (mmcfe/d) |
245 |
236 |
Royalties % |
2.9% |
2.8% |
Operating Cost ($/mcfe) |
$0.26 |
$0.25 |
Transportation Cost ($/mcfe) |
$0.50 |
$0.40 |
Operating netback ($/mcfe) |
$2.08 |
$2.29 |
Capital Expenditures ($ millions) |
$74 |
$249 |
Total Debt including working |
$223 |
$223 |
Capital expenditures in 2017 were $7 million higher than our guidance range due to our decision to add two incremental process equipment units as part of our plant expansion and the rig release of 4 additional wells as drilling times were faster than scheduled on our year-end well pad. One of the process units added was an electric power generator which will provide surplus electricity sales (2.4 MW) into the Alberta grid and the other process unit is a gas exchanger which will provide more flexibility and efficiency in the plant operation.
Looking Forward
The Sproule 2017 reserve report demonstrates another year of highly efficient reserve additions at Glacier reinforcing the exceptional quality of our Montney asset and the outstanding achievements of our team who accomplished this in a safe and environmentally responsible manner. Advantage's disciplined approach has and continues to be critically important in advancing our Montney natural gas and liquids development such that attractive returns are generated over the long term for our shareholders. We look forward to reporting on our progress through 2018.
RESERVE SUMMARY TABLES
Company Gross (before royalties) Working Interest Reserves
Summary as at December 31, 2017
Light & Medium (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional (mmcf) |
Total Oil Equivalent (mboe) | |
Proved |
||||
Developed Producing |
4 |
4,482 |
455,763 |
80,454 |
Developed Non-producing |
- |
1,018 |
45,049 |
8,526 |
Undeveloped |
- |
17,557 |
1,197,147 |
217,082 |
Total Proved |
4 |
23,057 |
1,697,959 |
306,062 |
Probable |
1 |
8,711 |
594,258 |
107,757 |
Total Proved + Probable |
6 |
31,768 |
2,292,218 |
413,819 |
(1) |
Tables may not add due to rounding. |
Company Net Present Value of Future Net Revenue using Sproule price and cost forecasts (1)(2)(3)($000)
Before Income Taxes Discounted at | ||||
0% |
10% |
15% | ||
Proved |
||||
Developed Producing |
1,291,370 |
835,646 |
705,904 | |
Developed Non-producing |
172,031 |
91,582 |
75,218 | |
Undeveloped |
3,110,192 |
842,153 |
464,582 | |
Total Proved |
4,573,594 |
1,769,381 |
1,245,703 | |
Probable |
2,297,267 |
780,609 |
543,675 | |
Total Proved + Probable |
6,870,860 |
2,549,991 |
1,789,379 | |
(1) |
Advantage's light and medium oil, conventional natural gas and natural gas liquid reserves were evaluated using Sproule's product price forecast effective December 31, 2017 prior to the provision for income taxes, interests, debt services charges and general and administrative expenses. It should not be assumed that the discounted future net revenue estimated by Sproule represents the fair market value of the reserves. |
(2) |
Assumes that development of Glacier and Valhalla will occur, without regard to the likely availability to the Corporation of funding required for that development. |
(3) |
Future Net Revenue incorporates Managements' estimates of required abandonment and reclamation costs, including expected timing such costs will be incurred, associated with all wells, facilities and infrastructure. No abandonment and reclamation costs have been excluded. |
(4) |
Tables may not add due to rounding. |
Sproule Price Forecasts
The net present value of future net revenue at December 31, 2017 was based upon natural gas and natural gas liquids pricing assumptions prepared by Sproule effective December 31, 2017. These forecasts are adjusted for reserve quality, transportation charges and the provision of any applicable sales contracts. The price assumptions used over the next seven years are summarized in the table below:
Year |
Alberta AECO-C Natural Gas ($Cdn/mmbtu) |
Henry Hub Natural Gas ($US/mmbtu) |
Edmonton Propane ($Cdn/bbl) |
Edmonton Butane ($Cdn/bbl) |
Edmonton Pentanes Plus ($Cdn/bbl) |
Exchange Rate ($US/$Cdn) |
2018 |
2.85 |
3.25 |
26.06 |
48.73 |
67.72 |
0.79 |
2019 |
3.11 |
3.50 |
32.84 |
55.49 |
75.61 |
0.82 |
2020 |
3.65 |
4.00 |
35.41 |
57.65 |
78.82 |
0.85 |
2021 |
3.80 |
4.08 |
37.85 |
60.12 |
82.35 |
0.85 |
2022 |
3.95 |
4.16 |
39.29 |
61.32 |
84.07 |
0.85 |
2023 |
4.05 |
4.24 |
40.25 |
62.55 |
85.82 |
0.85 |
2024 |
4.15 |
4.33 |
41.23 |
63.80 |
87.61 |
0.85 |
Company Gross (before royalties) Working Interest Reserves Reconciliation (1):
Proved |
Light & (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional Gas (mmcf) |
Total Oil Equivalent (mboe) |
Opening balance Dec. 31, 2016 |
8.4 |
15,524 |
1,437,149 |
255,057 |
Extensions |
- |
1,274 |
30,677 |
6,387 |
Infill Drilling |
- |
61 |
9,610 |
1,663 |
Infill Future Offset |
- |
5,557 |
155,679 |
31,504 |
Improved recovery |
- |
- |
- |
- |
Technical revisions |
(7.8) |
1,242 |
169,399 |
29,468 |
Discoveries |
- |
- |
- |
- |
Acquisitions |
4.5 |
2 |
- |
14 |
Royalty Changes |
- |
(166) |
(20,901) |
(3,650) |
Economic factors |
- |
6 |
(222) |
(31) |
Production |
(0.7) |
(444) |
(83,432) |
(14,350) |
Closing balance at Dec. 31, 2017 |
4.4 |
23,057 |
1,697,959 |
306,062 |
Proved Plus Probable |
Light & (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional Gas (mmcf) |
Total Oil Equivalent (mboe) |
Opening balance Dec. 31, 2016 |
11.1 |
23,529 |
2,055,398 |
366,106 |
Extensions |
- |
1,988 |
51,520 |
10,574 |
Infill Drilling |
- |
77 |
11,987 |
2,074 |
Infill Future Offset |
- |
7,455 |
204,522 |
41,542 |
Improved recovery |
- |
- |
- |
- |
Technical revisions |
(10.5) |
(949) |
68,541 |
10,464 |
Discoveries |
- |
- |
- |
- |
Acquisitions |
5.7 |
2 |
- |
17 |
Royalty Changes |
- |
106 |
(15,929) |
(2,549) |
Economic factors |
- |
5 |
(389) |
(60) |
Production |
(0.7) |
(444) |
(83,432) |
(14,350) |
Closing balance at Dec. 31, 2017 |
5.6 |
31,768 |
2,292,218 |
413,819 |
(1) |
Technical revisions accounted for 45% of the total proved additions and 17% of the total proved plus probable additions. Percentage of each category calculated by dividing the technical revisions in the category by the total reserve additions in the same category before production. |
(2) |
Tables may not add due to rounding. |
Company Finding & Development Costs ("F&D")
Company 2017 F&D Costs – Gross (before royalties) Working Interest Reserves including Future Development Capital (1)(2)(3)
Proved |
Proved + Probable | |
Capital expenditures ($000) |
248,774 |
248,774 |
Net change in Future Development Capital ($000) |
135,279 |
62,202 |
Total capital ($000) |
384,053 |
310,976 |
Total mboe, end of year |
306,062 |
413,819 |
Total mboe, beginning of year |
255,057 |
366,106 |
Production, mboe |
14,350 |
14,350 |
Reserve additions, mboe |
65,355 |
62,063 |
2017 F&D costs ($/boe) |
$5.88 |
$5.01 |
2016 F&D costs ($/boe) |
$1.49 |
($0.06) |
Three-year average F&D costs ($/boe) |
$4.15 |
$3.11 |
(1) |
F&D costs are calculated by dividing total capital by reserve additions during the applicable period. Total capital includes both capital expenditures incurred and changes in FDC required to bring the proved undeveloped and probable reserves to production during the applicable period. Reserve additions is calculated as the change in reserves from the beginning to the ending of the applicable period excluding production. |
(2) |
The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated FDC generally will not reflect total finding and development costs related to reserves additions for that year. Changes in forecast FDC occur annually as a result of development activities, acquisition and disposition activities and capital cost estimates that reflect Sproule's best estimate of what it will cost to bring the proved undeveloped and probable reserves on production. |
(3) |
The change in FDC is primarily from incremental undeveloped locations. |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "guidance", "believe", "would" and similar expressions and include statements relating to, among other things, Advantage's expectation with respect to its liquid development, hedge positions, market diversification and low cost structure; the timing of when wells will be placed on restricted production and expectations as to when they will be produced unrestricted; timing of the installation of new infrastructure; the benefits associated with Advantage's infrastructure; Advantage's belief that its Glacier development will continue to be an industry leading North American low cost natural gas supply source; the expected timing of release of Advantage's 2017 financial and operational results; estimated number of drilling locations; Advantage's estimated fourth quarter and full year 2017 financial and operating results including production, royalties, operating costs, transportation cost, operating netback, capital expenditures and total debt including working capital; and Advantage's focus on advancing its Montney natural gas and liquids development to generate long term attractive investment returns. In addition, statements relating to "reserves" are by their nature forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. The recovery and reserve estimates of Advantage's reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.sedar.com ("SEDAR") and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects.
Management has included the above summary of assumptions and risks related to forward-looking information above and in its continuous disclosure filings on SEDAR in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this news release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This press release contains a number of oil and gas metrics, including F&D, operating netback, recycle ratio, EUR, reserve replacement and reserve life index, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes. Operating netback is calculated by adding natural gas and liquids sales with realized gains on derivatives and subtracting royalty expense, operating expense and transportation expense. Recycle ratio is calculated by dividing Advantage's fourth quarter operating netback by the calculated F&D of the applicable year and expressed as a ratio. Reserve replacement is calculated by dividing reserves net volume additions by the current annual production and expressed as a percentage. Reserve life index is calculated by dividing the total volume of reserves by the fourth quarter production rate and expressed in years. Reserves per share is calculated as the total volume of reserves divided by the number of common shares issued and outstanding at year end. Reserves per debt-adjusted share assumes the issuance of additional common shares at the closing trading price on the TSX necessary to extinguish outstanding debt at year end and is calculated as the total volume of reserves divided by the sum of the number of common shares issued and outstanding at year end and the debt at year end divided by the Corporation's closing trading price on the TSX at year end.
The recovery and reserve estimates of reserves provided in this news release are estimates only, and there is no guarantee that the estimated reserves will be recovered. Actual reserves may eventually prove to be greater than, or less than, the estimates provided herein.
This press release discloses drilling locations in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations are derived from the Corporation's most recent independent reserves evaluation as prepared by Sproule as of December 31, 2017 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include total debt to trailing cash flow ratio and operating netback. Total debt to trailing cash flow ratio is calculated as bank indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Funds from operations is based on cash provided by operating activities, before expenditures on decommissioning liability and changes in non-cash working capital, reduced for finance expense excluding accretion. Operating netback is calculated by adding natural gas and liquids sales with realized gains on derivatives and subtracting royalty expense, operating expense and transportation expense. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures.
References in this press release to short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicitative of long-term performance, or of ultimate recovery. Additionally, some rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage.
This press release and, in particular the information in respect of the Corporation's expected 2017 operating costs, capital expenditures and total debt and operating netback, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions, including the assumptions discussed above, and assumptions with respect to the costs and expenditures to be incurred by the Corporation, capital equipment and operating costs, foreign exchange rates, taxation rates for the Corporation, general and administrative expenses and the prices to be paid for the Corporation's production. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the FOFI or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. However, because this information is highly subjective and subject to numerous risks including the risks discussed above, it should not be relied on as necessarily indicative of future results. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
Certain financial and operating results included in this news release including production, operating costs, operating netback, capital expenditures and total debt including working capital are based on unaudited estimated results. These estimated results are subject to change upon completion of the Corporation's audited financial statements for the year ended December 31, 2017, and changes could be material. Advantage anticipates filing its audited financial statements and related management's discussion and analysis for the year ended December 31, 2017 on SEDAR on March 5, 2018.
The following abbreviations used in this press release have the meanings set forth below:
bbl |
one barrel |
bbls |
barrels |
bbls/d |
barrels per day |
bcf |
bllion cubic feet |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent of natural gas per day |
mbbl |
thousand barrels |
mboe |
thousand barrels of oil equivalent of natural gas |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmbtu |
million British thermal units |
mmcf/d |
million cubic feet per day |
mmcfe/d |
million cubic feet equivalent per day |
tcf |
trillion cubic feet |
tcfe |
trillion cubic feet equivalent |
SOURCE Advantage Oil & Gas Ltd.
Increased Focus on Liquids Development & Growth Driven by Strong Well Results Underpins 2018 Cash Flow Funded Capital Budget
(TSX: AAV, NYSE: AAV)
CALGARY, Dec. 11, 2017 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to announce that its Board of Directors has approved a 2018 capital budget of $175 million funded through cash flow that prudently advances our industry leading low cost Montney development and results in increasing liquids production growth through 2018 and beyond from our assets at Glacier, Valhalla, Wembley and Progress.
Advantage's significant and growing inventory of commercial liquids rich natural gas development opportunities was recently extended by a 4 well pad at Valhalla which demonstrated a combined initial production flow rate of 6,410 boe/d comprised of 32 mmcf/d gas and 1,075 bbls/d of liquids (based on Glacier gas plant shallow cut extraction process) with certain liquid yields comprised of 90% free condensate/oil in excess of 100 bbls/mmcf. Middle Montney results at Glacier in 2017 also extended our liquids rich fairway and confirmed well performance improvements from frac design technology changes which will be applied to high liquids rich areas and reservoir layers within our Montney lands. In addition, well results from our liquids rich lands at Wembley and Progress are expected to be available by early 2018.
The Corporation's 2018 budget has been designed with significant flexibility to modify capital expenditures, capital allocation and production in H2 2018 or 2019 while advancing our liquids development initiative. The Corporation's 2018 capital budget of $175 million maintains a year-end 2018 total debt to cash flow of 1.3x (AECO price of Cdn $1.75/mcf & WTI $55 US/bbl) and provides for:
2018 Budget & Guidance Commentary
Glacier Development
Capital investment at Glacier in 2018 is targeted at $145 million, allowing flexibility during the year to modify spending, since the majority of well operations are planned in the second half. Planned expenditures includes $35 million to complete our Glacier gas plant expansion. Well operations include completion and equipping of standing wells that were drilled in 2017 and a second half 2018 drilling program that is weighted toward liquids rich wells.
Advantage's 2018 production target is supported by a year-end 2017 inventory of 12 completed standing wells, 18 drilled standing wells and available Glacier gas plant capacity. The number of wells drilled in the second half of 2018 can be varied sufficiently to provide the option for a broad range of production in 2019, subject to investment returns and commodity prices.
Completion of the Glacier gas plant expansion by the second quarter of 2018 increases raw gas processing capacity from 250 mmcf/d to 400 mmcf/d with propane plus ("C3+") liquids handling capacity increasing to 6,800 bbls/d. This expansion has been designed to accommodate gas and liquids compositions from the Valhalla and Progress areas and provides immediate cost efficiencies for processing Valhalla liquids rich natural gas in 2018. This also allows for efficient processing of additional liquids rich natural gas from the Middle Montney at Glacier and our undeveloped lands as Advantage increases its focus on developing its liquids rich Montney resources.
Additional infrastructure expenditures include a new sales gas meter station on the Alliance Pipeline system, continuing expansion of the field gas gathering system and installation of power lines to begin selling surplus Glacier electrical power into the Alberta grid. These initiatives provide options to further diversify markets, create additional revenue and maintain cost efficiencies.
Valhalla, Wembley and Progress
Advantage's 2018 budget includes an investment of $30 million to advance delineation and development of our three land blocks at Valhalla, Wembley and Progress which consist of 94 sections (60,160 net acres) of land outside of Glacier. The $30 million includes $20 million to install a compressor station at Valhalla and $10 million to drill 2 land retention wells at Progress (which were delayed from 2017) and the equipping and tie-in of our Wembley well.
Each land block consists of approximately 30 contiguous sections within the liquids rich areas of Valhalla, Wembley and Progress. These land blocks create the economies of scale to support scalable drilling programs and are located such that production economics can be enhanced by connecting back to our Glacier gas plant. Advantage's 94 sections of lands outside Glacier were acquired for a total cost of $18 million.
Recent Valhalla 4 Well Pad Exceeds Expectations with a Combined Initial Production Rate of 6,410 boe/d (32 mmcf/d and 1,075 bbls/d of liquids)
Advantage recently completed a 4-well pad at Valhalla. These wells were drilled in the Upper and Middle Montney with an average lateral length of 1,300 meters with a frac spacing of 46 meters at an average drill, complete, equip and tie-in cost of $4.6 million per well. The wells demonstrated an average gas production rate of 8.1 mmcf/d at an average flowing pressure of 9,725 kpa after an average 80 hour flow period. Individual well C3+ liquid yields of 20 bbls/mmcf to in-excess of 100 bbls/mmcf with free condensate and/or oil compositions of up to 90% were recovered. Advantage utilized reduced frac spacing and different mechanical systems compared to its initial three Valhalla evaluation wells and achieved an initial natural gas productivity improvement of 320%. The three earlier wells have been produced in-line to our Glacier gas plant through a smaller diameter pipeline without compression and have demonstrated low decline behavior over 12 months of production.
The new four well pad will be initially produced at restricted rates by free flowing into the existing pipeline starting in the second quarter of 2018 until the compressor station is completed by the fourth quarter of 2018. The new 40 mmcf/d Valhalla compressor station provides a cost effective initial infrastructure investment to facilitate future development. These initial well results support economic development and are further enhanced by accessing additional low cost gas processing capacity provided by Advantage's 100% owned Glacier gas plant and infrastructure. The compressor station is also located such that production from other land blocks could be tied-in and transported to our Glacier gas plant. Future plans to expand this facility and the gathering pipeline to Glacier will be evaluated in 2018.
Advantage believes continued refinement of completion techniques including longer laterals and more frac stages in this liquids corridor could continue to further improve future results as it has at Glacier. The Corporation's advanced frac technology expertise will be applied to east Glacier (higher liquids) as well as our other undeveloped lands.
Progress and Wembley
Completion operations are continuing in each of these land blocks and we expect results in early 2018.
Annual 2018 Guidance
Average annual production |
255 to 265 mmcfe/d | |
(42,500 to 44,170 boe/d) | ||
Liquids Annual |
1,900 bbls/d | |
Liquids Exit |
2,400 bbls/d | |
Royalty rate |
3% to 5% | |
Operating costs |
$0.25 to $0.29/mcfe | |
Transportation costs |
$0.52 to $0.58/mcfe | |
Total corporate cash costs |
$1.00 to $1.20/mcfe (1) | |
Capital expenditures |
$175 million |
Note: (1) The increase in transportation costs over 2017 is attributable to gas transportation tolls to the Dawn, Ontario market where current prices are approximately $2.00/mcf higher than AECO. This market for Advantage commenced in November 2017 and physically diversifies approximately 20% of our current production. |
Commodity Risk Management, Transportation and Market Diversification
In conjunction with our 2018 budget, Advantage's strong hedging positions for 2018 and 2019 reduces cash flow volatility. For the fourth quarter of 2017, the Corporation has hedged 56% of its natural gas production at Cdn $3.27/mcf and 61% for the first quarter of 2018 at Cdn $3.34/mcf. For 2018 and 2019, our hedging positions are 37% of estimated production at Cdn $3.32/mcf and 16% of estimated production at Cdn $3.02/mcf, respectively. These prices include both AECO and Dawn hedged prices.
Additionally, the Corporation has secured increasing levels of firm NGTL gas transportation service through 2020 and retains the ability to reduce our total commitments through existing evergreen contracts. This provides Advantage with the option to consider additional physical market diversification, in addition to our Dawn exposure, while managing our cumulative long term transportation exposure.
Beyond 2018
Advantage's recent well results at Valhalla confirms significant commercial liquids resources extending beyond the Middle Montney at Glacier. As a result, the Corporation is allocating more investment to increase liquids production growth by focusing development and delineation on areas which are expected to contain high natural gas liquids content, while capitalizing on low production cost efficiencies provided by its Glacier gas plant and infrastructure network.
We believe in the current environment, Advantage's continuing focus on capital discipline, cost efficiencies, profitability and financial strength will remain key success factors in achieving strong investment returns. Advantage has developed a 2018 budget that maintains significant financial and operational flexibility while advancing initiatives to improve netbacks and confirm value in all of our land blocks. We look forward to reporting our continued progress and achievements as we develop our high quality Montney resource.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the design of Advantage's 2018 and beyond development program; the applicability of frac design technology; the expected timing of well results from Wembley and Progress; Advantage's anticipated cash flow, total debt to cash flow, total corporate cash costs and production increase (including the percentage of liquids production) for 2018; Advantage's 2018 capital program, including the amount thereof, the amount to be allocated to advance liquids rich development at Valhalla, Wembley and Progress; timing and costs associated with infrastructure expansion and new infrastructure; benefits to be derived from infrastructure expansion and the development of new infrastructure; the Corporation's delineation drilling plans on its Montney lands located at Valhalla, Wembley and Progress; Advantage's anticipated annual production (including the percentage of natural gas production), royalty rates, operating costs, transportation costs and total corporate cash costs for 2018; the Corporation's expectation that total capital required from 2018 and beyond will be fully funded from cash flow; Advantage's belief that its industry leading low cost structure will continue; Advantage's future hedging positions, its beliefs related to the volatility of natural gas prices and its belief that such hedging positions are expected to reduce cash flow volatility; expectations regarding Advantage's 2018 approach; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; DCET well costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the year ended 2018 are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2018 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2018 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive.
These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This press release contains a number of oil and gas metrics, including reserve additions, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes.
References in this press release to short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage.
This press release and, in particular the information in respect of the Corporation's prospective total debt to cash flow, total cash costs, operating costs, capital expenditures, annual cash flow and transportation costs, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions, including the assumptions discussed above, and assumptions with respect to the costs and expenditures to be incurred by the Corporation, capital equipment and operating costs, foreign exchange rates, taxation rates for the Corporation, general and administrative expenses and the prices to be paid for the Corporation's production. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the FOFI or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. However, because this information is highly subjective and subject to numerous risks including the risks discussed above, it should not be relied on as necessarily indicative of future results. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
The following abbreviations used in this press release have the meanings set forth below:
bbl |
barrel |
bbls |
barrels |
bbl/d |
barrel per day |
bbls/d |
barrels per day |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
kpa |
kilopascal |
mcf |
thousand cubic feet |
mmcf/d |
million cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
Production Up, Cash Costs Down & Increased Hedging Further Reinforces Operational Strength and Financial Flexibility
(TSX: AAV, NYSE: AAV)
CALGARY, Nov. 2, 2017 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that its continued focus on financial discipline, operational excellence and prudent capital allocation has resulted in solid results during the third quarter and nine months of 2017. The third quarter was very active with well operations at all of our Montney land blocks and high construction activity levels at our Glacier gas plant expansion project. Capital expenditures for the quarter were $90 million of which 85% was invested to develop well productivity and to expand our facility infrastructure capacities for 2018 development and beyond. Additionally, the Corporation's cash flow has maintained our strong balance sheet with a total debt to cash flow ratio of 1.0 at the end of the third quarter. These results and additional achievements in the quarter enhances the Corporation's operational and financial flexibility and continues the ongoing successful execution of our multi-year development plan.
Cash flow for the quarter was $36.7 million or $0.20/share and $139.3 million or $0.75/share for the nine months, an increase of 21% as compared to the nine months of 2016. Advantage received a natural gas and liquids price of $2.46/mcfe ($14.76/boe) which included realized hedging gains of $0.40/mcfe. This resulted in a strong cash flow margin of 71% made possible by our industry leading low corporate cash costs of $0.73/mcfe for the third quarter of 2017, despite an AECO daily natural gas price that averaged $1.46/mcf.
Production was up 6% to 228.2 mmcfe/d (38,030 boe/d) for the third quarter and up 18% to 232.8 mmcfe/d (38,795 boe/d) for the nine months, on-track with our annual production guidance range of 230 mmcfe/d to 240 mmcfe/d. Natural gas liquids were up 16% to 1,395 bbls/d (75% condensate) and represented 14% of total revenue. These production gains were achieved despite significant TransCanada Pipeline Limited ("TCPL") transportation restrictions which occurred due to maintenance and pipeline system upgrading work during the quarter.
Total corporate cash costs were $0.73/mcfe during the third quarter and $0.87/mcfe for the nine months (including royalties, operating costs, transportation expense, G&A and finance expense). During the third quarter, operating costs were maintained at an industry leading low cost of $0.25/mcfe resulting from continued optimization of our water disposal and equipment maintenance costs.
The Corporation also made the following accomplishments during the third quarter of 2017 which enhances future flexibility and continues to prove up our significant resource upside:
Increased natural gas hedging positions to 56% of natural gas production for the fourth quarter of 2017 at Cdn $3.27/mcf and 61% for the first quarter of 2018 at Cdn $3.34/mcf. For 2018 and 2019, we increased our hedging positions to 37% of production at Cdn $3.32/mcf and 16% of production at Cdn $3.02/mcf, respectively.
Market diversification currently includes fixed price hedges, Henry Hub and Dawn market exposures and access to the Alliance pipeline in 2018 which will provide opportunities into the mid-west U.S. Advantage's AECO exposure for this upcoming winter is 9%, 43% in 2018 and 54% in 2019.
Developed current standing completed well productivity of 100 mmcf/d ("IP30") at Glacier with additional wells to be drilled by year-end 2017 to provide sufficient production capability in support of our 2018 production.
Middle Montney success advanced in west Glacier with two new wells that exceed current type curves. Strong well productivity was achieved in two separate Glacier Middle Montney layers through the application of refined completion and frac designs.
Completed the drilling of 6 wells on our undeveloped lands at Valhalla, Progress and Wembley to satisfy land expiries and to begin delineating the multiple layers of the Montney reservoir which have demonstrated encouraging results on adjacent industry lands.
Recent Glacier Achievements Include Strong Middle Montney Well Results Which Enhances Future Operational Flexibility
We completed 15 out of 16 wells that were previously drilled on our largest single pad to date at Glacier. Eleven of the 15 wells were Upper and Lower Montney wells which were individually produced in-line to our Glacier gas plant to ascertain flow capabilities. Based on initial production rates for these wells, we estimate an average IP30 of 7.7 mmcf/d per well with several wells exhibiting rates of over 10 mmcf/d. These wells have an average horizontal lateral length of 2,050 meters and were fracture stimulated with up to 30 frac stages and 63 frac ports utilizing an average of 70 tonnes of proppant per frac stage (up to 880 lbs/ft). Advantage utilized multiple mechanical completion techniques on this pad including cased ports, open hole and Stage Completions systems. The wells are expected to be placed on-stream as required through 2018 to support the Corporation's planned growth. The average drill, complete, equipping and tie-in cost of these wells was $4.7 million per well, on-track with our budget expectations.
Two Middle Montney wells on the 16 well pad located in west Glacier demonstrated excellent results in an area where there has been limited Middle Montney drilling to date. One well was drilled and completed in the second layer of the Middle Montney with an estimated IP30 of 7.8 mmcf/d. An additional well was drilled and completed in the third layer of the Middle Montney with an estimated IP30 of 5.1 mmcf/d. This was the first horizontal well drilled in this specific layer of the Middle Montney in west Glacier. These wells were completed using modified frac techniques, as compared to earlier Middle Montney wells, to evaluate short and longer term production impacts. As expected, these two Middle Montney wells confirmed that the average recoverable propane plus ("C3+") liquids yield of the Middle Montney wells in west Glacier is approximately 26 bbls/mmcf as compared to east Glacier which averages 50 bbls/mmcf.
The expansion of Advantage's 100% owned Glacier gas plant to a raw processing capacity of 400 mmcf/d is progressing on-schedule with project completion targeted for early in the second quarter of 2018. This plant expansion is anticipated to support our future production growth to approximately 2021 based on our current annual growth rate and/or accommodate third party processing opportunities.
Delineation Drilling and Completion Activities Proceeding as Planned on New Undeveloped Lands at Progress, Valhalla and Wembley
Advantage began delineation drilling on its 94 net Montney sections of undeveloped lands outside of Glacier in the third quarter with four wells drilled in Valhalla and one well drilled in each of the Progress and Wembley land blocks. Completion activities at Valhalla are currently underway while well completions at Progress and Wembley are anticipated to begin before year-end. The Valhalla well results are expected to be available in the fourth quarter and are planned to be brought on-production after the Glacier gas plant expansion is commissioned and increased gas gathering pipeline capacity between Valhalla and Glacier is completed in 2018. Two additional wells at Progress are scheduled to be rig released during the first quarter of 2018.
Increased Commodity Risk Management Positions and Market Diversification
Advantage increased its natural gas fixed price hedging positions to 56% of natural gas production for the fourth quarter of 2017 at Cdn $3.27/mcf and 61% of production for the first quarter of 2018 at Cdn $3.34/mcf. For 2018 and 2019, our hedging positions increased to 37% of production at Cdn $3.32/mcf and 16% of production at Cdn $3.02/mcf, respectively. Advantage capitalized on its previously secured strong basis positions and Dawn exposure to add attractive fixed price hedging contracts which continue to provide downside cash flow protection. The Corporation's industry leading low cost structure also provides us with the ability to hedge at lower prices while still generating attractive cash margins.
On November 1, 2017, we began transporting 55,600 GJ/d (52,700 mcf/d) from Alberta to the Dawn market in Southern Ontario through participation in TCPL's long term fixed price service open season. This provides physical market diversification of approximately 20% of our current production. Advantage has internally approved proceeding with a new sales gas meter station on the Alliance Pipeline system. We anticipate completion of the meter station in 2018.
Advantage's market diversification as a percentage of estimated total future production, net of royalties, are illustrated below:
Market Diversification |
2017 Q4 |
2018 |
2019 | |
Natural Gas |
||||
Fixed Prices (1) |
54% |
35% |
15% | |
AECO |
27% |
43% |
54% | |
Dawn |
15% |
10% |
16% | |
Henry Hub |
- |
8% |
9% | |
Liquids |
4% |
4% |
6% |
(1) |
Advantage has exposure to commodity price risk at various market hubs and therefore may fix prices at multiple markets. Please refer to the Consolidated Financial Statements and Management's Discussion and Analysis for additional information. |
Looking Forward
Advantage is on-track with its 2017 annual guidance and has developed increased financial and operational flexibility for 2018 and beyond. We will continue our strategy of sustainable and profitable growth while exercising financial discipline and prudent capital allocation as we finalize our 2018 budget plans which are expected to be released prior to year-end 2017.
Advantage's Montney development at Glacier has been successfully executed since 2008 based on maintaining an industry leading low cost structure, preserving a strong balance sheet, mitigating downside cash flow volatility and preserving operational flexibility. These factors, in conjunction with a disciplined focus on investment returns, will serve us well in the future.
Third Quarter 2017 Operating & Financial Summary Table
Three months ended |
Nine months ended | |||||||||||
Financial and Operating Highlights |
September 30 |
September 30 | ||||||||||
2017 |
2016 |
2017 |
2016 | |||||||||
Financial ($000, except as otherwise indicated) |
||||||||||||
Sales including realized hedging |
$ |
51,706 |
$ |
56,697 |
$ |
193,832 |
$ |
143,937 | ||||
Funds from operations |
$ |
36,722 |
$ |
45,132 |
$ |
139,319 |
$ |
112,251 | ||||
per share (1) |
$ |
0.20 |
$ |
0.24 |
$ |
0.75 |
$ |
0.62 | ||||
Total capital expenditures |
$ |
89,798 |
$ |
35,640 |
$ |
175,051 |
$ |
97,971 | ||||
Working capital deficit (2) |
$ |
37,017 |
$ |
5,023 |
$ |
37,017 |
$ |
5,023 | ||||
Bank indebtedness |
$ |
156,351 |
$ |
178,971 |
$ |
156,351 |
$ |
178,971 | ||||
Basic weighted average shares (000) |
185,953 |
184,572 |
185,533 |
181,188 | ||||||||
Operating |
||||||||||||
Daily Production |
||||||||||||
Natural gas (mcf/d) |
219,812 |
207,332 |
225,480 |
191,970 | ||||||||
Liquids (bbls/d) |
1,395 |
1,205 |
1,215 |
903 | ||||||||
Total mcfe/d (3) |
228,182 |
214,562 |
232,770 |
197,388 | ||||||||
Total boe/d (3) |
38,030 |
35,760 |
38,795 |
32,898 | ||||||||
Average prices (including hedging) |
||||||||||||
Natural gas ($/mcf) |
$ |
2.26 |
$ |
2.71 |
$ |
2.87 |
$ |
2.52 | ||||
Liquids ($/bbl) |
$ |
46.95 |
$ |
45.58 |
$ |
52.18 |
$ |
46.19 | ||||
Cash netbacks ($/mcfe) (3) |
||||||||||||
Natural gas and liquids sales |
$ |
2.06 |
$ |
2.27 |
$ |
2.80 |
$ |
1.80 | ||||
Realized gains on derivatives |
0.40 |
0.60 |
0.25 |
0.86 | ||||||||
Royalty (expense) recovery |
0.02 |
(0.08) |
(0.08) |
(0.02) | ||||||||
Operating expense |
(0.25) |
(0.25) |
(0.25) |
(0.29) | ||||||||
Transportation expense (4) |
(0.35) |
(0.05) |
(0.36) |
(0.03) | ||||||||
Operating netback |
1.88 |
2.49 |
2.36 |
2.32 | ||||||||
General and administrative |
(0.07) |
(0.09) |
(0.10) |
(0.11) | ||||||||
Finance expense |
(0.08) |
(0.11) |
(0.08) |
(0.14) | ||||||||
Other income |
0.01 |
- |
- |
0.01 | ||||||||
Cash netbacks |
$ |
1.74 |
$ |
2.29 |
$ |
2.18 |
$ |
2.08 |
(1) |
Based on basic weighted average shares outstanding. |
(2) |
Working capital deficit (surplus) includes trade and other receivables, prepaid expenses and deposits, and trade and other accrued liabilities. |
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of liquids. |
(4) |
Commencing on November 1, 2016, Advantage requested that its natural gas marketing contract be modified to reflect natural gas transportation as a cost. Prior to November 1, 2016, Advantage's realized natural gas prices were reduced for natural gas transportation from the sales points to AECO. This change has no effect on cash flow, cash netbacks, or net income; however, Advantage believes this is more instructive for our investors to compare cost structures going forward. |
Interim Consolidated Financial Statements and MD&A
The Corporation's unaudited interim condensed consolidated financial statements for the three and nine months ended September 30, 2017 together with the notes thereto, and Management's Discussion and Analysis for the three and nine months ended September 30, 2017 have been filed on SEDAR and with the SEC and are available on the Corporation's website at
http://www.advantageog.com/investors/financial-reports/2017-2
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the Corporation's plans to continue development of its oil and natural gas resource contained within its land holdings and increase production; Advantage's anticipated annual 2017 production guidance range; the Corporation's drilling plans for 2017, including the anticipated number of wells to be drilled, completed and put on-stream and the expected timing thereof; the Corporation's belief that drilling additional wells in 2017 will provide the well capability to achieve its 2018 production target; estimated average cost to drill, complete, equip and tie-in wells; expected timing of completion of expansion of the Corporation's Glacier gas plant, including the anticipated raw processing capacity following such expansion; Advantage's expectation that the expansion of the Corporation's Glacier gas plant will support anticipated production growth and/or accommodate third party processing opportunities; anticipated timing of available well results from Valhalla and bringing wells on production; anticipated timing of service for meter station on the Alliance pipeline and the expected opportunities therefrom; Advantage's future hedging positions and the terms of the Corporation's derivative contracts; the Corporation's belief that it is on track to meet its 2017 annual production guidance and that it has significant financial and operational flexibility; the Corporation's plans to continue its strategy as it finalizes its 2018 budget plans and the anticipated timing of announcement of such budget plans; the Corporation's belief that its continued focus on prudent capital allocation and returns will serve it well in the future; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; failure to achieve production targets on timelines anticipated or at all; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; individual well productivity; lack of available capacity on pipelines; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; delay in completion of sales gas meter station on the Alliance Pipeline system; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form dated March 2, 2017 which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: timing of regulatory approvals, conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; well costs; expected annual production growth rate; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein are expressed as anticipated average production over the calendar year. In determining anticipated production for the years ended December 31, 2017 and 2018 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2017 and 2018 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains a number of oil and gas metrics, including operating netbacks, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes. Operating netback is calculated by adding natural gas and liquids sales with realized gains and losses on derivatives and subtracting royalty expense, operating expense and transportation expense.
References in this press release to IP30 rates and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include operating netbacks, cash netbacks, cash costs and total debt to cash flow ratio. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
The following abbreviations used in this press release have the meanings set forth below.
bbls/d |
barrels per day |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
GJ/d |
gigajoules per day |
mcf |
thousand cubic feet |
mcf/d |
thousand cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mcfe/d |
thousand cubic feet equivalent per day on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf/d |
million cubic feet per day |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
Strong Glacier Operating Results Generate Surplus Cash, Delineation Drilling Commenced at Progress, Valhalla & Wembley
(TSX: AAV, NYSE: AAV)
CALGARY, Aug. 3, 2017 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report solid second quarter 2017 results which met our targets. The results include a 32% increase in cash flow to $49 million with a 30% increase in cash flow per share to $0.26/share. Production increased 10% on a per share basis to 232 mmcfe/d (38,739 boe/d) with total corporate cash costs (including natural gas and liquids transportation) of $0.98/mcfe, inclusive of $0.27/mcfe of operating costs. The Corporation's balance sheet has been further strengthened by $17 million of surplus cash (cash flow less capital expenditures) generated from our operations during the first half of 2017, in addition to the $39 million of surplus cash generated in 2016. This has reduced Advantage's total debt by $52 million and lowered the Corporation's total debt to trailing cash flow ratio to 0.7 at the end of the second quarter of 2017 as compared to 1.5 at June 30, 2016.
During the second quarter, the Corporation increased its sales gas transportation options by initiating plans to construct a new sales gas meter station on the Alliance pipeline system for 2018 and recently secured incremental TransCanada Pipelines ("TCPL") firm sales gas transportation service on the intra-Alberta Nova Gas Transmission ("NGTL") system to facilitate continued annual production growth beyond 2019. As of April 2020, Advantage's TCPL firm sales gas transportation contracts will total 363 mmcf/d (exclusive of liquids production).
Advantage's Glacier 2017 development activities are progressing as planned with sufficient standing completed wells available to support our 2017 annual production target of 236 mmcfe/d (range of 230 mmcfe/d to 240 mmcfe/d) and an additional 16 well pad that has been drilled to support 2018 production growth. For the balance of 2017, these 16 wells will be completed and the drilling of additional wells at Glacier will be undertaken to sustain production in 2018. The expansion of Advantage's 100% owned Glacier gas plant to a raw processing capacity of 400 mmcf/d is progressing on-schedule with project completion targeted for the second quarter of 2018. Capital, production and costs at Glacier are on-track with our 2017 targets.
These results continue to demonstrate the exceptional quality of our Glacier Montney asset and reinforces the Corporation's focus on developing its Montney natural gas resource in a profitable and sustainable manner.
Three Year Development Plan & Glacier Gas Plant Expansion
Advantage's three year development plan is progressing on-track with a targeted average annual production growth of 16% per year including production targets of 236 mmcfe/d, 272 mmcfe/d and 316 mmcfe/d for 2017, 2018 and 2019, respectively. The expansion of Advantage's 100% owned Glacier gas plant from a raw processing capacity of 250 mmcf/d to 400 mmcf/d began in the second quarter of 2017 with on-site ground work initiated. Additional equipment deliveries and increasing levels of on-site construction will ramp up for the remainder of 2017 and through the first quarter of 2018. The ongoing plant expansion is also targeted to increase shallow-cut liquids extraction capacity to 6,800 bbls/d with the current design capable of processing natural gas and liquids compositions from Valhalla.
Upon completion of the Glacier gas plant expansion, Advantage anticipates having initial surplus raw gas processing capacity of approximately 140 mmcf/d to support the Corporation's 2017 through 2019 development plan and beyond, including options to consider accelerating production growth and/or accommodate third party processing opportunities.
Delineation Drilling at Progress, Valhalla and Wembley Commenced
During the first half of 2017, Advantage acquired and added 26 new sections of undeveloped Montney lands to our existing Progress and Valhalla land parcels. These 26 new sections were acquired through producer transactions for a total of $7 million in cash and fulfilled our strategy to build land parcels of sufficient size to provide economies of scale. Advantage's land holdings at Progress, Valhalla and Wembley are comprised of approximately 30 contiguous sections each in size and are located in the greater Glacier operating area, proximal to Advantage's 100% owned Glacier gas plant and pipelines. The Corporation's total undeveloped land holdings outside of Glacier have grown to a total of 90 net Montney sections (57,600 acres).
With the closing of the land acquisitions in the second quarter, Advantage has developed plans to advance delineation drilling in the second half of 2017 at Progress, Valhalla and Wembley. The delineation drilling program in these three areas will be undertaken in part for land retention purposes and to allow Advantage to begin accumulating key data and knowledge to integrate future investment in these areas into an overall Corporate area development plan to optimize returns. Advantage's second half 2017 delineation drilling plan includes a four-well pad at Valhalla, three wells at Progress and one well at Wembley (total of 7.4 net wells). Four of these wells will preserve a total of 42.6 net sections of land of which 9.8 net sections will be continued indefinitely and 32.8 net sections will be continued for an additional 5 years at Progress and Wembley. These lands are due to expire in 2017 and mid-2018 based on their original license terms. Advantage estimates that incremental capital expenditures of approximately $22 million will be spent during the second half of 2017 on this delineation drilling program.
The Progress, Valhalla and Wembley areas are estimated by Management to contain sufficient natural gas and liquids accumulations to support scalable drilling programs and economies of scale given their proximity to Advantage's Glacier gas plant and gathering system. In each of these areas, ongoing industry drilling activity has demonstrated encouraging initial results with high liquid yields and gas rates. Industry drilling adjacent to the Progress and Valhalla areas have targeted multiple Montney layers with results demonstrating liquids rich gas accumulations in all layers to date. At Wembley, industry producers have primarily targeted one of the Middle Montney layers which has demonstrated very high liquids yields comprised of both oil and condensate in the adjacent Pipestone field. Future industry drilling could evaluate up to four layers of Montney potential in this area.
Advantage's total Montney land holdings increased to a total of 180 net sections (115,200 acres) comprised of 90 sections at Glacier and 90 sections in the greater Glacier operating area.
Increasing Transportation Access, Market Diversification and Commodity Risk Management Program
Advantage has continued to proactively identify and manage its transportation and market diversification opportunities through multiple initiatives.
During the second quarter of 2017, Advantage initiated plans to construct a new sales gas meter station on the Alliance pipeline. The meter station is currently anticipated to be in-service in 2018 and is expected to provide opportunities to access take-away capacity directly into the US markets.
Additionally, Advantage recently executed agreements with TCPL for additional firm natural gas sales transportation service in April, 2020 on the NGTL system to increase the Corporation's contracted total firm transportation service to 363 mmcf/d (excluding natural gas liquids production). This extends the Corporation's previously secured increasing levels of firm sales gas transportation service in support of the Corporation's annual production targets of 236 mmcfe/d, 272 mmcfe/d and 316 mmcfe/d for 2017, 2018 and 2019, respectively.
In the first quarter of 2017, Advantage participated in TCPL's Mainline open season and committed for firm transportation service of 55,600 GJ/d (52,800 mcf/d) from Empress, Alberta to the Dawn market in Southern Ontario. This firm service commitment is expected to be effective November 1, 2017 and represents approximately 20% of Advantage's targeted 2018 average annual production. The firm service is conditional on National Energy Board approval and is on an expedited approval timeline process.
Advantage's multi-year commodity risk management program includes the following hedging positions:
% Estimated Future Natural |
Average AECO Cdn $/mcf | |
2017 |
45% |
$3.19/mcf |
2018 |
22% |
$3.08/mcf |
2019 Q1 |
18% |
$3.00/mcf |
Notes: (1) Based on estimates of average daily natural gas production, net of royalties |
Advantage has also secured Henry Hub to AECO basis differentials of US$0.85/mcf on 25,000 mcf/d for calendar 2018 and US$0.88/mcf on 50,000 mcf/d for calendar 2019.
Looking Forward and Guidance
Advantage's annual average production guidance of 236 mmcfe/d (range of 230 mmcfe/d to 240 mmcfe/d) remains unchanged with third quarter 2017 production anticipated to be similar to our second quarter. Maintenance, turnaround and expansion activities based on TCPL's schedule and based on Advantage's schedule are expected during the third quarter of 2017 and have been previously incorporated into our annual production guidance. Advantage expects NGTL's sales gas pipeline take-away capacity in the Upstream James River area will increase above historical levels in the fourth quarter of 2017.
Advantage's 2017 capital expenditure guidance has been increased from $205 million (range of $195 million to $215 million) to $234 million (range of $225 million to $242 million). The $29 million increase is comprised of $22 million for the delineation drilling program and $7 million for the successful land acquisitions in the first half of 2017.
The Corporation's 2017 annual operating cost guidance remains unchanged at $0.26/mcfe (range of $0.23/mcfe to $0.28/mcfe) and royalties are expected to be 5% (range of 4% to 6%).
Advantage's year-end total debt to trailing cash flow is estimated to be approximately 1.0 times based on an average 2017 AECO average natural gas price of Cdn $2.50/mcf including the Corporation's commodity hedges and based on the mid-points of guidance.
Second Quarter 2017 Operating and Financial Highlights
On a per share basis, cash flow increased 30% to $0.26/share and production grew 10% to 232 mmcfe/d (38,739 boe/d) during the second quarter of 2017 compared to the second quarter of 2016 through Advantage's continued focus on improving efficiencies.
Strong cash flow exceeded the second quarter 2017 capital program of $32 million and generated surplus cash of $17 million.
Total debt to trailing cash flow was reduced to 0.7 times as of June 30, 2017. Total debt (including working capital deficit) was $141 million at the end of the quarter.
Advantage's industry leading low total corporate cash costs including natural gas and liquids transportation costs were $0.98/mcfe during the second quarter of 2017. Operating costs were reduced 10% from the same period in 2016 and up slightly from the first quarter of 2017 from $0.23/mcfe to $0.27/mcfe due primarily to higher costs for road maintenance and trucking costs as a result of wet spring weather conditions.
Second Quarter 2017 Operating & Financial Summary Table
Three months ended |
Six months ended | |||||||||
Financial and Operating Highlights |
June 30 |
June 30 | ||||||||
2017 |
2016 |
2017 |
2016 | |||||||
Financial ($000, except as otherwise indicated) |
||||||||||
Sales including realized hedging |
$ |
69,169 |
$ |
45,615 |
$ |
142,126 |
$ |
87,240 | ||
Funds from operations |
$ |
48,625 |
$ |
36,883 |
$ |
102,597 |
$ |
67,119 | ||
per share(1) |
$ |
0.26 |
$ |
0.20 |
$ |
0.55 |
$ |
0.37 | ||
Total capital expenditures |
$ |
31,462 |
$ |
17,595 |
$ |
85,253 |
$ |
62,331 | ||
Working capital deficit (surplus)(2) |
$ |
6,950 |
$ |
(525) |
$ |
6,950 |
$ |
(525) | ||
Bank indebtedness |
$ |
134,128 |
$ |
194,028 |
$ |
134,128 |
$ |
194,028 | ||
Basic weighted average shares (000) |
185,790 |
184,477 |
185,319 |
179,478 | ||||||
Operating |
||||||||||
Daily Production |
||||||||||
Natural gas (mcf/d) |
225,844 |
203,791 |
228,363 |
184,204 | ||||||
Liquids (bbls/d) |
1,098 |
1,083 |
1,124 |
750 | ||||||
Total mcfe/d(3) |
232,432 |
210,289 |
235,107 |
188,704 | ||||||
Total boe/d(3) |
38,739 |
35,048 |
39,185 |
31,451 | ||||||
Average prices (including hedging) |
||||||||||
Natural gas ($/mcf) |
$ |
3.09 |
$ |
2.18 |
$ |
3.17 |
$ |
2.41 | ||
Liquids ($/bbl) |
$ |
57.27 |
$ |
52.67 |
$ |
55.47 |
$ |
46.69 | ||
Cash netbacks ($/mcfe)(3) |
||||||||||
Natural gas and liquids sales |
$ |
3.16 |
$ |
1.34 |
$ |
3.17 |
$ |
1.53 | ||
Realized gains on derivatives |
0.11 |
1.04 |
0.17 |
1.01 | ||||||
Royalty (expense) recovery |
(0.15) |
0.08 |
(0.13) |
0.01 | ||||||
Operating expense |
(0.27) |
(0.30) |
(0.25) |
(0.32) | ||||||
Transportation expense(4) |
(0.37) |
(0.03) |
(0.37) |
(0.02) | ||||||
Operating netback |
2.48 |
2.13 |
2.59 |
2.21 | ||||||
General and administrative |
(0.12) |
(0.10) |
(0.11) |
(0.11) | ||||||
Finance expense |
(0.07) |
(0.13) |
(0.08) |
(0.15) | ||||||
Other income |
0.01 |
0.02 |
- |
0.01 | ||||||
Cash netbacks |
$ |
2.30 |
$ |
1.92 |
$ |
2.40 |
$ |
1.96 |
(1) |
Based on basic weighted average shares outstanding. |
||||||||
(2) |
Working capital deficit (surplus) includes trade and other receivables, prepaid expenses and deposits, and trade and other accrued liabilities. |
||||||||
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of liquids. |
||||||||
(4) |
Commencing on November 1, 2016, Advantage requested that its natural gas marketing contract be modified to reflect natural gas transportation as a cost. Prior to November 1, 2016, Advantage's realized natural gas prices were reduced for natural gas transportation from the sales points to AECO. This change has no effect on cash flow, cash netbacks, or net income; however, Advantage believes this is more instructive for our investors to compare cost structures going forward. |
Interim Consolidated Financial Statements and MD&A
The Corporation's unaudited condensed interim consolidated financial statements for the three and six months ended June 30, 2017 together with the notes thereto, and Management's Discussion and Analysis for the three and six months ended June 30, 2017 have been filed on SEDAR and with the SEC and are available on the Corporation's website at http://www.advantageog.com/investors/financial-reports/2017-2.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the Corporation's plans to continue development of its Montney oil and natural gas resource contained within its land holdings and increase production, including the targeted amount of such production increase to be achieved by 2019; the Corporation's drilling plans for 2017, including the anticipated number of wells to be drilled and completed and the expected timing thereof; the anticipated benefits of the 2017 delineation drilling program in the greater Glacier operating area; the anticipated year-end total debt to trailing cash flow; timing of survey work for additional well locations at Progress and Wembley; anticipated timing of service for meter station on the Alliance pipeline and the expected opportunities therefrom; expectations regarding NGTL sales gas pipeline take-away capacity; the ability of TCPL to obtain the necessary regulatory approvals for the sales gas transportation service, anticipated number of future drilling locations and the Corporation's focus on developing such locations including the number of locations to be developed and the expected timing thereof; the proposed expansion of Advantage's Glacier gas plant processing capacity, including the anticipated timing that construction will commence and be completed on the proposed expansion; the Corporation's belief that its firm sales gas transportation service will satisfy its annual production targets from 2017 to 2019 including the potential to accelerate production growth; Advantage's estimated exposure to AECO prices in 2017; the Corporation's belief that its completed, standing wells will provide sufficient field production capability to increase annual production to its 2017 production target, including the amount of such production target; anticipated commodity prices; Advantage's future hedging positions; the Corporation's belief that taking a disciplined approach to managing commodity price risk for 2018 and beyond will be prudent as supply and demand fundamentals are expected to remain volatile; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form dated March 2, 2017 which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: timing of regulatory approvals, conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; well costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the years ended December 31, 2017, 2018 and 2019 are expressed as anticipated average production over the calendar year. In determining anticipated production for the years ended December 31, 2017, 2018 and 2019 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2017, 2018 and 2019 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains a number of oil and gas metrics, including operating netback, and reserve additions, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes. Operating netback is calculated by adding natural gas and liquids sales with realized gains and losses on derivatives and subtracting royalty expense, operating expense and transportation expense.
References in this press release to IP30 rates and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This press release discloses drilling locations in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations are derived from the Corporation's most recent independent reserves evaluation as prepared by Sproule Associates Limited as of December 31, 2016 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Of the 1,100 drilling locations disclosed in this press release, 793 are unbooked locations. Unbooked locations are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which Advantage actually drills wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include operating netbacks, cash netbacks, surplus cash and total debt to trailing cash flow ratio. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities. The following abbreviations used in this press release have the meanings set forth below.
This press release and, in particular the information in respect of the Corporation's prospective cash flow debt to trailing cash flow ratio, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
bbls/d |
barrels per day |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
GJ/d |
gigajoules per day |
mcf |
thousand cubic feet |
mcf/d |
thousand cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mcfe/d |
thousand cubic feet equivalent per day on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf/d |
million cubic feet per day |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, May 25, 2017 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage") is pleased to announce that on May 25, 2017 it held its annual general and special meeting of shareholders (the "Meeting"). A total of 151,241,262 common shares (approximately 81.34% of the outstanding common shares) were represented at the Meeting in person or by proxy.
At the Meeting, shareholders approved the election of six nominees as directors of Advantage to serve until the next annual meeting of shareholders or until their successors are elected or appointed, with the number and percentage of common shares represented at the Meeting voting by way of ballot in favour or withheld from voting for the individual nominees as follows:
FOR |
WITHHELD | ||||||
Number |
Percentage |
Number |
Percentage | ||||
Jill T. Angevine |
142,183,468 |
99.10% |
1,292,696 |
0.90% | |||
Stephen E. Balog |
142,184,600 |
99.10% |
1,291,564 |
0.90% | |||
Grant B. Fagerheim |
141,651,341 |
98.73% |
1,824,823 |
1.27% | |||
Paul G. Haggis |
142,091,577 |
99.03% |
1,384,587 |
0.97% | |||
Andy J. Mah |
142,453,422 |
99.29% |
1,022,742 |
0.71% | |||
Ronald A. McIntosh |
138,948,852 |
96.84% |
4,527,312 |
3.16% |
For complete voting results, please see our Report of Voting Results available on SEDAR at www.sedar.com.
SOURCE Advantage Oil & Gas Ltd.
42% Increase in Production to 238 mmcfe/d (39,635 boe/d),
79% Increase in Cash Flow to $54 million
and a 39% Increase in Undeveloped Montney Land Holdings
(TSX: AAV, NYSE: AAV)
CALGARY, May 4, 2017 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that first quarter 2017 production increased 42% over the same period of 2016 and 8% over the fourth quarter of 2016 to a record level of 238 mmcfe/d (39,635 boe/d). Cash flow increased 79% to $54 million which fully funded our capital expenditures of $54 million and included the completion of all well operations required to support our 2017 production target. Since January 1, 2017 the Corporation has acquired 24 net sections of strategic Montney land and entered into a long term commitment to further diversify our natural gas markets.
On a per share basis, production grew 34% to 238 mmcfe/d (39,635 boe/d) and cash flow grew 71% to $0.29/share during the first quarter of 2017 through Advantage's continued focus on improving efficiencies. The Corporation reduced its operating costs by 34% to $0.23/mcfe ($1.38/boe) and total corporate cash costs by 18% to $0.89/mcfe ($5.34/boe) including natural gas and liquids transportation.
Strong cash flow fully funded our capital program of $54 million and resulted in a total debt to trailing cash flow of 0.8 times as of March 31, 2017. Total debt (including working capital deficit) was $159 million at the end of the quarter.
Advantage increased its undeveloped Montney land holdings by 39% through the acquisition of 24 net sections (15,360 net acres) at our Progress and Valhalla areas for an aggregate cash cost of $6 million. Since 2008, Advantage has increased its total Montney land holding by 125% from 79 net sections (50,560 acres) to 178 net sections (113,920 acres) with 87 net sections (55,680 acres) now located at Valhalla, Progress and Wembley, proximal to our 100% owned Glacier gas plant and gathering system. These 87 net sections are located in three contiguous land blocks and have natural gas liquids and multi-zone development potential.
Advantage committed to 55,600 GJ/day (52,800 mcf/d) of firm sales gas transportation service on Trans Canada Pipelines ("TCPL") mainline from Empress, Alberta to the Dawn market in Southern Ontario through TCPL's open season in the first quarter of 2017. This service is expected to commence on November 1, 2017 and includes a 10 year term at a toll of $0.77/GJ. Approval of this service is subject to TCPL obtaining the necessary regulatory approvals which are progressing in an expedited application process. This will further diversify Advantage's end-markets and complement our attractive AECO natural gas price hedges and Henry Hub to AECO basis differentials that have been secured through 2019.
Activity Update and Looking Forward
Well Operations
Advantage completed 11 new Montney gas wells that were drilled prior to year-end 2016 which will be utilized to support our 2017 production target of 236 mmcfe/d. We also concluded drilling operations on a 16-well pad in the first quarter of 2017 which is scheduled to be completed during the second half of 2017. Production from this pad is scheduled to be brought on-stream in 2018 to support the Corporation's development plan growth. The Corporation's current standing well inventory consists of 28 wells of which 11 are drilled and completed and 17 remain uncompleted. Advantage's completed well productivity is estimated to have a combined average 30 day initial production rate ("IP30") of 65 mmcf/d, sufficient to support our 2017 annual production target of 236 mmcfe/d. These completed wells consist of 7 Upper and Lower Montney wells and 4 Middle Montney wells.
Increased Montney Undeveloped Land
Advantage's acquisition of 24 net Montney sections has strategically expanded our Progress area and further complemented our Valhalla land holdings. In addition to the 91 net sections of Montney land at Glacier, Advantage now owns 87 net sections of Montney land (100% operated and controlled) which represents three separate contiguous assets in the greater Glacier area. These 87 net sections are comprised of 29 sections located at Progress, 30 sections located at Valhalla and 28 sections located at Wembley. Each of these asset areas are estimated by Management to contain sufficient natural gas and liquids accumulations to support scalable drilling programs and economies of scale given their proximity to our Glacier gas plant and gathering system. Delineation drilling is required to optimize and schedule future development planning in order to continue Advantage's track record of delivering strong returns and sustainable growth. Advantage drilled and is producing three liquids rich Montney wells at Valhalla and plans to drill a new four well pad during the second half of 2017. At Wembley and Progress, Advantage plans to spud delineation wells in each of these areas in the fourth quarter of 2017. Industry drilling adjacent to Progress, Valhalla and Wembley have continued to demonstrate the potential for liquids rich and multi-zone development.
Glacier Gas Plant Expansion
Advantage received license approval from the Alberta Energy Regulator for the expansion of our 100% owned Glacier gas plant to a processing capacity of 400 mmcf/d of raw gas and 6,800 bbls/d of shallow-cut liquids extraction capability. The plant expansion also included engineering design changes for the processing of natural gas and liquids compositions from the greater Glacier area. All major equipment items have been procured and shop fabrication is well underway. On-site construction will begin in the second half of 2017 and is anticipated to be completed by the second quarter of 2018. At such time, Advantage anticipates having initial surplus raw processing capacity of approximately 140 mmcf/d to support our 2017 through 2019 corporate growth plan and beyond, accelerated production growth and/or accommodate third party processing opportunities.
Commodity Price Risk Management, Transportation & Market Diversification
Advantage's multi-year commodity risk management program includes the following hedging positions:
% Estimated Future Natural |
Average AECO Cdn $/mcf | |
2017 Remainder of Year |
45% |
$3.07/mcf |
2018 |
22% |
$3.02/mcf |
2019 Q1 |
18% |
$3.00/mcf |
Notes: (1) Based on estimates of average daily natural gas production, net of royalties |
Advantage has also secured Henry Hub to AECO basis differentials of US$0.85/mcf on 25,000 mcf/d for calendar 2018 and US$0.88/mcf on 50,000 mcf/d for calendar 2019.
In order to further diversify our markets, Advantage participated in TCPL's Mainline open season in the first quarter of 2017 and committed for firm transportation service of 55,600 GJ/d (52,800 mcf/d) from Empress, Alberta to the Dawn market in Southern Ontario. This firm service commitment is expected to be effective November 1, 2017 and represents approximately 20% of our targeted 2018 average annual production. The toll is $0.77/GJ for a 10 year take-or-pay term that can be reduced at Advantage's option by up to 5 years, subject to the terms of the contract. The firm service is conditional on National Energy Board approval and is on an expedited approval timeline process.
On the intra-Alberta Nova Gas Transmission Ltd's ("NGTL") system, Advantage has secured increasing levels of firm sales gas transportation service of up to 308 mmcf/d which will satisfy 100% of the Corporation's annual production targets of 236 mmcfe/d, 272 mmcfe/d and 316 mmcfe/d for 2017, 2018 and 2019, respectively.
Advantage's 2017 through 2019 Development Plan is On-Track
Advantage is well positioned and on-track to continue executing on its 2017 through 2019 development plan which is expected to increase production by 56% to 316 mmcfe/d (52,670 boe/d) or 16% on an average annual basis.
Advantage 2017 production is targeted to achieve an annual average rate of approximately 236 mmcfe/d with a range of 230 to 240 mmcfe/d. Maintenance, turnaround and expansion activities based on TCPL's schedule and based on Advantage's schedule are expected during the second and third quarters of 2017 and have been previously incorporated into our annual production target and guidance. Advantage also expects NGTL's sales gas pipeline take-away capacity in the Upstream James River area will increase above historical levels in the fourth quarter of 2017.
Advantage's achievements in the first quarter of 2017 reinforced the Corporation's execution strength and the increase in our undeveloped Montney land holdings are expected to significantly supplement our Glacier future drilling inventory of over 1,100 locations and extend growth for decades to come.
First Quarter 2017 Operating and Financial Highlights
(refer to summary table at the end of this release)
First quarter 2017 production was up 42% to a record 238 mmcfe/d (39,635 boe/d), representing a 34% increase on a per share basis. Liquids production was up 175% to 1,151 bbls/d as compared to the first quarter of 2016. Production increased through the addition of new Montney wells and the utilization of additional processing capacity at our 100% owned Glacier gas plant.
Operating costs in the first quarter of 2017 were reduced by 34% to $0.23/mcfe ($1.38/boe) compared to the same period of 2016. This achievement was made possible due to continued efficiency improvements, streamlined equipment maintenance procedures and higher plant throughput. Total corporate cash costs were reduced 18% to $0.89/mcfe as compared to the same period of 2016, including gas and liquids transportation. Total corporate cash costs includes royalties ($0.10/mcfe), operating costs ($0.23/mcfe), transportation ($0.38/mcfe), cash general and administrative ($0.10/mcfe), and cash finance expense ($0.08/mcfe). (Note that natural gas transportation costs were previously deducted from revenue and are now included as an expense as of November 1, 2016. This has no impact on the Corporation's historical or go forward netbacks).
Funds from operations (cash flow) for the first quarter of 2017 was up 79% to $54 million and up 71% on a per share basis to $0.29, including hedging gains of $5 million. Advantage's operating netback was $2.70/mcfe ($16.20/boe) and cash netback was $2.52/mcfe ($15.12/boe) which represents 74% of the realized sales price, including hedging.
Net capital expenditures during the quarter were $54 million and funded entirely through cash flow.
Total debt to trailing twelve-month cash flow was reduced to 0.8x at March 31, 2017. This achievement was attained despite an average daily AECO natural gas price of $2.38/mcf during the twelve-month trailing period. Total debt (including working capital deficit) as of March 31, 2017 was $159 million.
Subsequent to March 31, 2017, Advantage's Credit Facilities borrowing base was renewed at $400 million. Advantage's bank debt of $148 million represents a 37% draw against Advantage's $400 million borrowing base credit facility at the end of the first quarter of 2017.
Interim Consolidated Financial Statements and MD&A
The Corporation's unaudited condensed interim consolidated financial statements for the three months ended March 31, 2017 together with the notes thereto, and Management's Discussion and Analysis for the three months ended March 31, 2017 have been filed on SEDAR and with the SEC and are available on the Corporation's website at http://www.advantageog.com/investors/financial-reports/2017-2.
First Quarter 2017 Operating & Financial Summary
Three months ended | |||||
Financial and Operating Highlights |
March 31 | ||||
2017 |
2016 | ||||
Financial ($000, except as otherwise indicated) |
|||||
Sales including realized hedging |
$ |
72,957 |
$ |
41,625 | |
Funds from operations |
$ |
53,972 |
$ |
30,236 | |
per share(1) |
$ |
0.29 |
$ |
0.17 | |
Net capital expenditures |
$ |
53,791 |
$ |
44,736 | |
Working capital deficit(2) |
$ |
10,895 |
$ |
10,666 | |
Bank indebtedness |
$ |
147,781 |
$ |
202,538 | |
Basic weighted average shares (000) |
184,842 |
174,479 | |||
Operating |
|||||
Daily Production |
|||||
Natural gas (mcf/d) |
230,906 |
164,618 | |||
Liquids (bbls/d) |
1,151 |
418 | |||
Total mcfe/d(3) |
237,812 |
167,126 | |||
Total boe/d(3) |
39,635 |
27,854 | |||
Average realized prices (including hedging) |
|||||
Natural gas ($/mcf) |
$ |
3.24 |
$ |
2.70 | |
Liquids ($/bbl) |
$ |
53.73 |
$ |
31.21 | |
Cash netbacks ($/mcfe)(3) |
|||||
Natural gas and liquids sales |
$ |
3.17 |
$ |
1.77 | |
Realized gains on derivatives |
0.24 |
0.97 | |||
Royalties |
(0.10) |
(0.07) | |||
Operating expense |
(0.23) |
(0.35) | |||
Transportation expense (4) |
(0.38) |
(0.01) | |||
Operating netback |
2.70 |
2.31 | |||
General and administrative |
(0.10) |
(0.13) | |||
Finance expense |
(0.08) |
(0.19) | |||
Cash netbacks |
$ |
2.52 |
$ |
1.99 |
(1) |
Based on basic weighted average shares outstanding. |
(2) |
Working capital deficit includes trade and other receivables, prepaid expenses and deposits, and trade and other accrued liabilities. |
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of liquids. |
(4) |
Commencing on November 1, 2016, Advantage requested that its gas marketing contract be modified to reflect natural gas transportation as a cost. Prior to November 1, 2016, Advantage's realized natural gas prices were reduced for natural gas transportation from the sales points to AECO. This change has no effect on funds from operations, cash netbacks, or net income; however, Advantage believes this is more instructive for our investors to compare cost structures going forward. |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the Corporation's plans to continue development of its Montney oil and natural gas resource contained within its land holdings and increase production, including the targeted amount of such production increase to be achieved by 2019; the Corporation's drilling plans for 2017, including the anticipated number of wells to be drilled and completed and the expected timing thereof; the ability of TCPL to obtain the necessary regulatory approvals for the sales gas transportation service, anticipated number of future drilling locations and the Corporation's focus on developing such locations including the number of locations to be developed and the expected timing thereof; the proposed expansion of Advantage's Glacier gas plant processing capacity, including the anticipated timing that construction will commence and be completed on the proposed expansion; the Corporation's belief that its firm sales gas transportation service will satisfy its annual production targets from 2017 to 2019; Advantage's estimated exposure to AECO prices in 2017; the Corporation's belief that its completed, standing wells will provide sufficient field production capability to increase annual production to its 2017 production target, including the amount of such production target; anticipated commodity prices; Advantage's future hedging positions; the Corporation's belief that taking a disciplined approach to managing commodity price risk for 2018 and beyond will be prudent as supply and demand fundamentals are expected to remain volatile; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form dated March 2, 2017 which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: timing of regulatory approvals, conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; well costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the years ended December 31, 2017, 2018 and 2019 are expressed as anticipated average production over the calendar year. In determining anticipated production for the years ended December 31, 2017, 2018 and 2019 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2017, 2018 and 2019 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains a number of oil and gas metrics, including operating netback, and reserve additions, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes. Operating netback is calculated by adding natural gas and liquids sales with realized gains and losses on derivatives and subtracting royalty expense, operating expense and transportation expense.
References in this press release to IP30 rates and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production of Advantage.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This press release discloses drilling locations in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations are derived from the Corporation's most recent independent reserves evaluation as prepared by Sproule Associates Limited as of December 31, 2016 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Of the 1,100 drilling locations disclosed in this press release, 793 are unbooked locations. Unbooked locations are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which Advantage actually drills wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include operating netbacks, cash netbacks, surplus cash and total debt to trailing cash flow ratio. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.The following abbreviations used in this press release have the meanings set forth below.
This press release and, in particular the information in respect of the Corporation's prospective cash flow debt to trailing cash flow ratio, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
bbls/d |
barrels per day |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
GJ/d |
gigajoules per day |
mcf |
thousand cubic feet |
mcf/d |
thousand cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mcfe/d |
thousand cubic feet equivalent per day on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf/d |
million cubic feet per day |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
Record Results and Outperformance Underscores
Low Cost Glacier Montney Natural Gas Supply
& Continuing Growth
(TSX: AAV, NYSE: AAV)
CALGARY, March 2, 2017 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report the Corporation outperformed its 2014 through 2016 Glacier Montney development plan objectives and achieved record operating and financial results in 2016. During the last three years, Advantage transformed into a North American leading low cost Montney natural gas and liquids producer with strong investment returns despite extended periods of historically low commodity prices. As we embark on our 2017 through 2019 development plan and beyond, our achievements have further strengthened the Corporation's capacity to continue delivering profitable and sustainable growth based on a disciplined strategy supported by a strong hedging program, market diversification and firm transportation service. As we continue growth from our fourth quarter 2016 production rate of 221 mmcfe/d (36,844 boe/d) to a target of 316 mmcfe/d (52,670 boe/d) in 2019, we are excited to continue development of our vast Montney natural gas and liquids resource contained within the Corporation's land holdings.
We sincerely thank Advantage's Board of Directors and our shareholders for their guidance and ongoing support. We especially wish to thank our staff for their dedication and extra-efforts who have contributed to the Corporation's success in achieving stellar 2016 results and for their accomplishments in the last three years which are summarized below.
Resource Delineation and Capture
During the last three years, the Corporation grew its Montney land holdings by 30% through the acquisition of 36 net sections (23,040 net acres) of targeted high quality lands through Alberta government land sales and producer transactions for a total cost of $13 million. These sections were high graded based on Advantage's geo-technical interpretations and complement the Corporation's existing Montney land holdings. Since 2008, a total of 181 Montney horizontal wells have been drilled at Glacier leading to commercialization of five development layers which are estimated to contain approximately 1,100 future drilling locations. At our Valhalla land block, we have drilled three initial evaluation wells which confirmed natural gas liquids and an additional four wells are planned to be drilled in 2017. At our Wembley and Progress land blocks, industry drilling, in close proximity to our lands, have demonstrated encouraging results and Advantage plans to drill initial evaluation wells within the next 12 to 18 months. Advantage currently has a total of 157 net sections (100,480 net acres) of Montney lands which is 100% operated and controlled.
Operational Excellence
Over the last three years, Advantage increased annual production by 74% (61% per share) to 203 mmcfe/d (33,890 boe/d) and reduced operating costs per mcfe by 44% to $0.27/mcfe ($1.62/boe) in 2016. Through the application of new technologies in conjunction with Advantage's Montney expertise, significant improvements in well performance combined with lower well and facilities costs contributed to improving all-in capital efficiencies to $7,330/boe/d in 2016. Reserves additions have been achieved at an average three year proved plus probable finding and development ("F&D") cost of $0.46/mcfe ($2.76/boe) and proved F&D cost of $0.75/mcfe ($4.53/boe) including the change in future development capital. Advantage's 100% owned Glacier gas plant was expanded from 160 mmcf/d in 2014 to 250 mmcf/d in 2016 with a current expansion underway to further increase raw processing capacity to 400 mmcf/d by the second quarter of 2018. These achievements have created a solid foundation for a continued industry leading low cost structure and targeted production growth to 316 mmcfe/d (52,670 boe/d) in 2019.
Financial Strength
Advantage reduced its year-end total debt from $289 million in 2013 to $159 million in 2016 including reductions in its total capital program requirements by $177 million, growing its cash flow by 96% (81% per share) and achieving hedging gains of $73 million during the last three years. Total corporate cash costs were reduced by 53% to $0.66/mcfe ($3.96/boe) in 2016 resulting in strong operating netbacks of $2.83/mcfe ($16.98/boe) in the fourth quarter of 2016. Advantage generated $39 million of surplus cash (funds from operations less capital) in 2016 which contributed to a strong balance sheet with a 2016 year-end total debt to trailing cash flow ratio of 1.0 and an undrawn credit facility of $247 million to provide significant financial flexibility. Additionally, a commodity risk management and market diversification program is in place through 2019 to provide downside commodity price protection. As a result, Advantage's 2017 through 2019 development plan is highly resilient and estimated to result in a total 2019 year-end debt to trailing cash flow ratio of 0.2 assuming a three year AECO natural gas price assumption of Cdn $2.95/mcf. Assuming an average three year AECO natural gas price assumption of Cdn $2.00/mcf or $3.50/mcf, total 2019 year-end debt to trailing cash flow ratios are estimated to be 1.4 or 0.0, including the Corporation's current hedging positions, respectively.
Commodity Risk Management, Transportation and Market Diversification
Advantage has continued with a multi-year commodity risk management program in conjunction with its Montney development which began in 2008. The volume and price targets related to our hedging positions have and will continue to vary based on future capital program content. Since we have significantly reduced our corporate cash costs and improved capital efficiencies, a smaller volume of hedging, even at lower commodity prices than historical levels, can generate strong returns. Advantage has also proactively secured increasing levels of firm sales gas transportation service of up to 308 mmcf/d which will satisfy 100% of the Corporation's annual production targets (natural gas and liquids) of 236 mmcfe/d, 272 mmcfe/d and 316 mmcfe/d for 2017, 2018 and 2019, respectively. We have diversified our end-markets by securing Henry Hub to AECO basis differentials of US$0.85/mcf on 25,000 mcf/d for calendar 2018 and US$0.88/mcf on 50,000 mcf/d for calendar 2019. Our exposure to AECO prices are estimated to be approximately 57% in 2017.
The Corporation's achievements and strategic positioning further bolsters our confidence in the future development of Advantage's Montney assets to continue generating attractive investment returns and to compete as an industry leading North American natural gas and liquids supply source. We look forward to reporting on our development plan execution over the next three years.
Note: Please refer to Advantage's Year-end 2016 Reserves press release dated February 7, 2017 for additional details. F&D costs are calculated by dividing total capital by reserve additions during the applicable period. Total capital includes both capital expenditures incurred and changes in future development capital required to bring proved undeveloped reserves and probable reserves to production during the applicable period. Reserve additions are calculated as the change in reserves from the beginning to the end of the applicable period excluding production.
2016 Operating and Financial Highlights (please refer to the summary table at the end of this release)
Fourth quarter 2016 production was up 42% to a record 221 mmcfe/d (36,844 boe/d) and up 44% to average 203 mmcfe/d (33,890 boe/d) in 2016 representing a 36% increase on a per share basis. Liquids production was up 494% on an annual basis to 915 bbls/d as compared to 2015. The Corporation's strategy to maintain excess Montney well productivity and to retain available processing capacity at its 100% owned Glacier gas plant provided operational flexibility to capitalize on strengthening gas prices and to offset TransCanada Pipeline Limited's ("TCPL") sales gas transportation restrictions during 2016 and particularly in the fourth quarter of 2016.
Operating costs in the fourth quarter of 2016 were reduced by 37% to a record low of $0.22/mcfe ($1.32/boe) and reduced on an annual basis by 25% to $0.27/mcfe ($1.62/boe) compared to the same periods of 2015. This outstanding achievement was made possible by Advantage's continued focus on operational excellence and through the dedicated efforts of our Montney team.
Strong cash flow growth resulted in $39 million of surplus cash (funds from operations less capital expenditures) during 2016. Annual cash flow was up 35% to $167 million and up 28% on a per share basis to $0.92 which included hedging gains of $53 million. Advantage's cash netback for 2016 was $2.24/mcfe ($13.44/boe) which represents 78% of the realized sales price, including hedging.
Total debt (including working capital deficit) was reduced by $134 million to $159 million during 2016 resulting in a year-end 2016 total debt to trailing cash flow of approximately 1.0x. These achievements were attained despite an average daily AECO natural gas price of $2.16/mcf during 2016. Capital spending during the fourth quarter of 2016 was $30 million and $128 million for 2016.
Current Activity Update and Looking Forward
Advantage currently has 13 completed, standing wells which are expected to provide sufficient field production capability to increase annual production by 16% to our 2017 production target of 236 mmcfe/d (39,337 boe/d). The average drill, complete, equipping and tie-in costs for the 13 wells based on actual costs to date and Management estimates are $4.4 million/well which reflects Advantage's structural cost reductions as well as the continuation of lower service costs in 2016. A new 16 well pad will be rig released in the first quarter of 2017 and will be completed during the latter part of this year to support production growth through 2018.
The Corporation's Glacier gas plant expansion to increase raw processing capacity from 250 mmcf/d to 400 mmcf/d, including increasing propane plus ("C3+") liquids extraction capacity to 6,800 bbls/d, is progressing on-track. Approval has been received from the Alberta Energy Regulator ("AER") and engineering design and equipment orders have been completed. Construction is expected to commence during the second half of 2017 with completion targeted by the second quarter of 2018.
To achieve our 2017 through 2019 production growth, a total of approximately 83 new Montney wells will be required to be drilled out of our estimated drilling inventory of 1,100 future locations at Glacier. This is targeted to drive annual production growth by 53% to 316 mmcfe/d (52,670 boe/d) in 2019. Operational flexibility to allow for increasing growth targets and varying the number of dry gas wells versus liquids rich wells have been included in our development plan.
Commodity Risk Management Program & Market Diversification
Advantage has hedged 45% of its 2017 targeted natural gas production at an average AECO price of Cdn $3.19/mcf, 22% of 2018 targeted natural gas production at an average AECO price of Cdn $3.02/mcf and 18% of Q1 2019 targeted natural gas production at an average AECO price of Cdn $3.00/mcf (% hedged is net of royalties). Additionally, we have secured Henry Hub to AECO basis differentials of US$0.85/mcf on 25,000 mcf/d for calendar 2018 and US$0.88/mcf on 50,000 mcf/d for calendar 2019 to diversify our natural gas markets.
We believe taking a disciplined approach to managing commodity price risk for 2018 and beyond will be prudent as supply and demand fundamentals are expected to remain volatile.
Consolidated Financial Statements and MD&A
The Corporation's audited consolidated financial statements for the fiscal year ended December 31, 2016 together with the notes thereto, and Management's Discussion and Analysis for the year ended December 31, 2016 have been filed on SEDAR and with the SEC and are available on the Corporation's website at http://www.advantageog.com/investors/financial-reports/2016. The Corporation's audited consolidated financial statements for the fiscal year ended December 31, 2015 are also available on the Corporation's website via the same webpage. Upon request, Advantage will provide a hard copy of any financial reports free of charge.
Fourth Quarter and Full Year 2016 Operating & Financial Summary
Three months ended |
Year ended | ||||||||
Financial and Operating Highlights |
December 31 |
December 31 | |||||||
2016 |
2015 |
2016 |
2015 | ||||||
Financial ($000, except as otherwise indicated) |
|||||||||
Sales including realized hedging |
$ |
71,090 |
$ |
42,654 |
$ |
215,027 |
$ |
165,054 | |
Funds from operations |
$ |
54,610 |
$ |
31,656 |
$ |
166,861 |
$ |
123,630 | |
per share(1) |
$ |
0.30 |
$ |
0.19 |
$ |
0.92 |
$ |
0.72 | |
Total capital expenditures |
$ |
30,043 |
$ |
27,604 |
$ |
128,014 |
$ |
164,983 | |
Working capital deficit(2) |
$ |
6,167 |
$ |
7,196 |
$ |
6,167 |
$ |
7,196 | |
Bank indebtedness |
$ |
153,102 |
$ |
286,519 |
$ |
153,102 |
$ |
286,519 | |
Basic weighted average shares (000) |
184,641 |
170,742 |
182,056 |
170,608 | |||||
Operating |
|||||||||
Daily Production |
|||||||||
Natural gas (mcf/d) |
215,369 |
154,241 |
197,852 |
139,927 | |||||
Liquids (bbls/d) |
949 |
179 |
915 |
154 | |||||
Total mcfe/d(3) |
221,063 |
155,315 |
203,342 |
140,851 | |||||
Total boe/d(3) |
36,844 |
25,886 |
33,890 |
23,475 | |||||
Average prices (including hedging) |
|||||||||
Natural gas ($/mcf) |
$ |
3.35 |
$ |
2.96 |
$ |
2.75 |
$ |
3.18 | |
Liquids ($/bbl) |
$ |
53.01 |
$ |
43.24 |
$ |
47.97 |
$ |
44.60 | |
Cash netbacks ($/mcfe)(3) |
|||||||||
Natural gas and liquids sales |
$ |
3.17 |
$ |
2.37 |
$ |
2.18 |
$ |
2.57 | |
Realized gains on derivatives |
0.32 |
0.61 |
0.71 |
0.64 | |||||
Royalties |
(0.18) |
(0.10) |
(0.07) |
(0.11) | |||||
Operating expense |
(0.22) |
(0.35) |
(0.27) |
(0.36) | |||||
Transportation expense (4) |
(0.26) |
- |
(0.09) |
- | |||||
Operating netback |
2.83 |
2.53 |
2.46 |
2.74 | |||||
General and administrative |
(0.08) |
(0.11) |
(0.10) |
(0.14) | |||||
Finance expense |
(0.09) |
(0.21) |
(0.13) |
(0.21) | |||||
Other income (expense) |
0.02 |
(0.01) |
0.01 |
0.01 | |||||
Cash netbacks |
$ |
2.68 |
$ |
2.20 |
$ |
2.24 |
$ |
2.40 |
(1) |
Based on basic weighted average shares outstanding. |
(2) |
Working capital deficit includes trade and other receivables, prepaid expenses and deposits, and trade and other accrued liabilities. |
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of liquids. |
(4) |
Please note that commencing on November 1, 2016, Advantage requested that its gas marketing contract be modified to reflect natural gas transportation as a cost. Prior to November 1, 2016, Advantage's realized natural gas prices were reduced for natural gas transportation from the sales points to AECO. This change has no effect on funds from operations, cash netbacks, or net income (loss), however, Advantage believes this is more instructive for our investors to compare cost structures going forward. |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the Corporation's plans to continue development of its Montney oil and natural gas resource contained within its land holdings and increase production, including the targeted amount of such production increase to be achieved by 2019; the Corporation's drilling plans for 2017, including the anticipated number of wells to be drilled and completed and the expected timing thereof; anticipated number of future drilling locations and the Corporation's focus on developing such locations including the number of locations to be developed and the expected timing thereof; the proposed expansion of Advantage's Glacier gas plant processing capacity, including the anticipated timing that construction will commence and be completed on the proposed expansion; the Corporation's belief that its firm sales gas transportation service will satisfy its annual production targets from 2017 to 2019; Advantage's estimated exposure to AECO prices in 2017; the Corporation's belief that its completed, standing wells will provide sufficient field production capability to increase annual production to its 2017 production target, including the amount of such production target; anticipated commodity prices; Advantage's future hedging positions; the Corporation's belief that taking a disciplined approach to managing commodity price risk for 2018 and beyond will be prudent as supply and demand fundamentals are expected to remain volatile; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; well costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the years ended December 31, 2017, 2018 and 2019 are expressed as anticipated average production over the calendar year. In determining anticipated production for the years ended December 31, 2017, 2018 and 2019 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2017, 2018 and 2019 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains a number of oil and gas metrics, including F&D cost, operating netback, and reserve additions, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes. Operating netback is calculated by adding natural gas and liquids sales with realized gains and losses on derivatives and subtracting royalty expense, operating expense and transportation expense.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This press release discloses drilling locations in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations are derived from the Corporation's most recent independent reserves evaluation as prepared by Sproule Associates Limited as of December 31, 2016 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Of the 1,100 drilling locations disclosed in this press release, 793 are unbooked locations. Unbooked locations are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which Advantage actually drills wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include operating netbacks, cash netbacks, surplus cash and total debt to trailing cash flow ratio. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
kpa |
kilopascal |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
Record Low Proved Developed Producing Reserve Addition Cost of $0.84/mcfe ($5.04/boe) Underscores Outperformance In All Reserve Categories
(TSX: AAV, NYSE: AAV)
CALGARY, Feb. 7, 2017 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that the Corporation achieved record low reserves addition costs and capital efficiencies in 2016 which continues to demonstrate the ongoing strength of its industry leading low cost and profitable natural gas development at its Glacier Montney property. Year-on-year gains in well production performance generated significant positive technical revisions that accounted for 46% of proved plus probable ("2P") reserve additions while Advantage's development and delineation drilling program at Glacier contributed the balance of natural gas and liquids reserves additions. 2P reserves grew 13% to 2.2 Tcfe (366.1 million boe) including natural gas liquids which increased by 17% to 23.5 million barrels.
During 2016, Advantage brought 15 new wells on-production which helped increase annual production by 44% over 2015. These wells and the improved performance of historical producing wells contributed to a 26% increase in proved developed producing ("PDP") reserves at a record low finding and development ("F&D") cost of $0.84/mcfe ($5.04/boe) and a PDP recycle ratio of 3.4. The Corporation's 2P reserve additions replaced 429% of its 2016 annual production while lower future development capital combined with significant positive technical revisions resulted in a negative 2016 F&D cost of -$0.01/mcfe (-$0.06/ boe) and a three year average 2P F&D cost including the change in future development capital ("FDC") of $0.46/mcfe ($2.76/boe).
As the Corporation continues to advance its Montney growth plan and expand its 100% owned Glacier gas plant to 400 mmcf/d (66,670 boe/d), we believe Advantage's Glacier development is and will continue to be an industry leading and competitive North American low cost natural gas supply source as demonstrated by record achievements in its operating, financial and reserve addition results in 2016.
PDP reserves increased 26% to 381 Bcfe at a F&D cost of $0.84/mcfe ($5.04/boe). PDP reserves increased due to the recognition of 15 new wells that were brought on-production in 2016 and higher reserves assignments on historical producing wells due to shallower longer term declines than previously assumed.
Proved ("1P") reserves increased 20% to 1.53 Tcfe (255.1 million boe) at a F&D cost of $0.25/mcfe ($1.49/boe) including the change in FDC. Reserve increases resulted from technical revisions which accounted for 60% of the 1P reserves additions and the conversion of probable locations to the proved reserves category as a result of Advantage's successful drilling program.
2P reserves increased 13% to 2.20 Tcfe (366.1 million boe) at a F&D cost including the change in FDC of -$0.01/mcfe (-$0.06/boe). 2P FDC decreased by $131 million reflective of lower future well costs which were partly offset by increases in facilities costs to include an upsized Glacier gas plant expansion to 400 mmcf/d and future infrastructure costs including a frac water supply system, gas gathering system expansions and additional utilities. This reduction in FDC is due to Advantage's ongoing achievements in improving capital efficiencies and lowering costs which has reduced capital requirements to support growth. The 2016 2P reserves include an addition of 24 new Glacier Montney well locations including 10 undeveloped locations that were added in 2016. A total of 307 undeveloped locations were booked in the 2016 reserve report. Management estimates approximately 1,100 total Montney locations remain undrilled at Glacier.
The Corporation replaced 429% of its 2016 annual production on a 2P basis, 438% on a 1P basis and 206% on a PDP basis at Recycle Ratios of -266.6x (7.0x excluding the change in FDC), 11.4x and 3.4x, respectively. The strong recycle ratios reinforces Advantage's industry leading low cost structure which continues to support strong netbacks and profit margins. These recycle ratios included the Corporation's hedges and were achieved in the environment where the AECO daily natural gas price averaged Cdn $2.16/mcf in 2016.
At year-end 2016, Advantage's 2P reserves grew 13% and 18% on a debt adjusted basis and 1P reserves grew 20% and 26% on a debt adjusted per share basis compared to year-end 2015.
Since Advantage's Glacier Montney development program began in 2008, 2P reserves have grown 3,800% to 2.2 Tcfe (366.1 million boe) with a 2P reserve Net Present Value of $2.2 Billion as at December 31, 2016 (10% discount factor on a pre-tax basis).
The cumulative efficiencies achieved to date have allowed the Corporation to continue to deliver profitable and sustainable growth. This is further reflected in our 2017 through 2019 strategic growth plan which is targeted to deliver 52% production growth per share (16% on an average annual production per share basis) while reducing estimated year-end total debt to trailing cash flow to 0.2x in 2019 at an average AECO natural gas price of Cdn $2.95/mcf ($2.80/GJ) as outlined in Advantage's "2017 Budget and Development Plan" press release dated November 28, 2016.
Notable 2016 Reserve Changes and Analysis
Sproule Associates Ltd. ("Sproule") was engaged as an independent qualified reserve evaluator to evaluate Advantage's year-end reserves as of December 31, 2016 ("Sproule 2016 reserve report") in accordance with National Instrument 51-101 ("NI 51-101") and the Canadian Oil and Gas Evaluation Handbook ("COGE Handbook"). Reserves are stated on a gross (before royalties) working interest basis unless otherwise indicated. Additional details are provided in the accompanying tables to this release and additional reserve information as required under NI 51-101 will be included in our Annual Information Form which will be filed on SEDAR on or before March 31, 2017.
All references to 2016 operational and financial results are estimates only and have not been reviewed or audited by our independent auditor. Advantage is expected to release its fourth quarter and year-end results after markets close on March 2, 2017.
Reserve |
Conventional |
NGLs |
Total Gas |
% Change from |
PDP |
0.36 |
3.65 |
0.38 |
26% |
1P |
1.44 |
15.53 |
1.53 |
20% |
2P |
2.06 |
23.54 |
2.20 |
13% |
Sproule # of Gross Horizontal Wells Booked |
Sproule Average EUR/well (bcf raw /well) | ||
Developed |
Undeveloped |
Undeveloped | |
Upper |
102 |
141 |
5.9 |
Middle |
22 |
82 |
4.9 |
Lower |
43 |
84 |
6.4 |
Total |
167 |
307 |
2016 Summary Results
During the fourth quarter of 2016 production increased 42% over the same period in 2015 to 221 mmcfe/d and Advantage outperformed its annual 2016 Guidance targets (please refer to Advantage's Operational Update press release dated January 18, 2017).
Key operational results during the fourth quarter of 2016 and for calendar 2016 are indicated below:
Q4 2016E |
2016E | ||
Production (mmcfe/d) |
221 |
203 | |
Royalties % |
5.6% |
3.0% | |
Operating Cost ($/mcfe) |
$0.22 |
$0.27 | |
Operating netback ($/mcfe) |
$2.83 |
$2.46 | |
Capital Expenditures ($ millions) |
$30 |
$128 | |
Total Debt including working capital ($ millions) |
$159 |
$159 |
(References to 2016 operational and financial results are estimates only and have not been reviewed or audited by our independent auditor. Advantage is expected to release its fourth quarter and year-end results after markets close on March 2, 2017)
Looking Forward
The Sproule 2016 reserve report demonstrates another year of highly efficient reserve additions at Glacier reaffirming the exceptional quality of our Montney asset and the outstanding achievements of our team who accomplished this in a safe and environmentally responsible manner. Looking ahead, Advantage remains highly focused on maintaining operational and financial flexibility in conjunction with growth plans that generate profitability during lower commodity price cycles while preserving significant upside torque. We look forward to reporting on our progress through 2017.
RESERVE SUMMARY TABLES
Company Gross (before royalties) Working Interest Reserves
Summary as at December 31, 2016
Light & Medium (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional (mmcf) |
Total Oil (mboe) | |
Proved |
||||
Developed Producing |
8 |
3,645 |
358,980 |
63,484 |
Developed Non-producing |
- |
597 |
50,736 |
9,053 |
Undeveloped |
- |
11,281 |
1,027,433 |
182,520 |
Total Proved |
8 |
15,524 |
1,437,149 |
255,057 |
Probable |
3 |
8,005 |
618,249 |
111,049 |
Total Proved + Probable |
11 |
23,529 |
2,055,398 |
366,106 |
(1) Tables may not add due to rounding. |
Company Net Present Value of Future Net Revenue using Sproule price and cost forecasts (1)(2)(3)
($000)
Before Income Taxes Discounted at | |||
0% |
10% |
15% | |
Proved |
|||
Developed Producing |
1,084,909 |
720,793 |
616,180 |
Developed Non-producing |
186,551 |
90,765 |
72,810 |
Undeveloped |
2,587,841 |
614,694 |
298,395 |
Total Proved |
3,859,301 |
1,426,251 |
987,386 |
Probable |
2,384,445 |
787,492 |
546,369 |
Total Proved + Probable |
6,243,745 |
2,213,743 |
1,533,754 |
(1) |
Advantage's light and medium oil, conventional natural gas and natural gas liquid reserves were evaluated using Sproule's product price forecast effective December 31, 2016 prior to the provision for income taxes, interests, debt services charges and general and administrative expenses. It should not be assumed that the discounted future net revenue estimated by Sproule represents the fair market value of the reserves. |
(2) |
Assumes that development of Glacier will occur, without regard to the likely availability to the Corporation of funding required for that development. |
(3) |
Future Net Revenue incorporates Managements' estimates of required abandonment and reclamation costs, including expected timing such costs will be incurred, associated with all wells, facilities and infrastructure. No abandonment and reclamation costs have been excluded. |
(4) |
Tables may not add due to rounding. |
Sproule Price Forecasts
The net present value of future net revenue at December 31, 2016 was based upon natural gas and natural gas liquids pricing assumptions prepared by Sproule effective December 31, 2016. These forecasts are adjusted for reserve quality, transportation charges and the provision of any applicable sales contracts. The price assumptions used over the next seven years are summarized in the table below:
Year |
Alberta AECO-C Natural Gas ($Cdn/mmbtu) |
Henry Hub Natural Gas ($US/mmbtu) |
Edmonton Propane ($Cdn/bbl) |
Edmonton Butane ($Cdn/bbl) |
Edmonton Pentanes Plus ($Cdn/bbl) |
Exchange Rate ($US/$Cdn) |
2017 |
3.44 |
3.50 |
22.74 |
47.60 |
67.95 |
0.78 |
2018 |
3.27 |
3.50 |
28.04 |
55.49 |
75.61 |
0.82 |
2019 |
3.22 |
3.50 |
30.64 |
57.65 |
78.82 |
0.85 |
2020 |
3.91 |
4.00 |
32.27 |
58.80 |
80.47 |
0.85 |
2021 |
4.00 |
4.08 |
33.95 |
59.98 |
82.15 |
0.85 |
2022 |
4.10 |
4.16 |
35.68 |
61.18 |
83.86 |
0.85 |
2023 |
4.19 |
4.24 |
37.46 |
62.40 |
85.61 |
0.85 |
Company Gross (before royalties) Working Interest Reserves Reconciliation (1):
Proved |
Light & (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional Gas (mmcf) |
Total Oil Equivalent (mboe) |
Opening balance Dec. 31, 2015 |
9.4 |
12,097 |
1,206,484 |
213,187 |
Extensions |
- |
3,166 |
142,211 |
26,868 |
Infill Drilling |
- |
- |
- |
- |
Improved recovery |
- |
- |
- |
- |
Technical revisions |
0.5 |
846 |
190,852 |
32,655 |
Discoveries |
- |
- |
- |
- |
Acquisitions |
- |
- |
- |
- |
Royalty Changes |
- |
(166) |
(20,901) |
(3,650) |
Economic factors |
(0.1) |
(86) |
(9,087) |
(1,600) |
Production |
(1.4) |
(334) |
(72,410) |
(12,404) |
Closing balance at Dec. 31, 2016 |
8.4 |
15,524 |
1,437,149 |
255,057 |
Proved Plus Probable |
Light & (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional Gas (mmcf) |
Total Oil Equivalent (mboe) |
Opening balance Dec. 31, 2015 |
12.2 |
20,121 |
1,831,284 |
325,347 |
Extensions |
- |
3,966 |
174,684 |
33,080 |
Infill Drilling |
- |
- |
- |
- |
Improved recovery |
- |
- |
- |
- |
Technical revisions |
0.5 |
(225) |
149,264 |
24,653 |
Discoveries |
- |
- |
- |
- |
Acquisitions |
- |
- |
- |
- |
Royalty Changes |
- |
106 |
(15,929) |
(2,549) |
Economic factors |
(0.2) |
(106) |
(11,495) |
(2,022) |
Production |
(1.4) |
(334) |
(72,410) |
(12,404) |
Closing balance at Dec. 31, 2016 |
11.1 |
23,529 |
2,055,398 |
366,106 |
(1) |
Technical revisions accounted for 60% of the total proved additions and 46% of the total proved plus probable additions. Percentage of each category calculated by dividing the technical revisions in the category by the total reserve additions in the same category before production. |
(2) |
Tables may not add due to rounding. |
Company Finding & Development Costs ("F&D")
Company 2016 F&D Costs – Gross (before royalties) Working Interest Reserves including Future Development Capital (1)(2)(3)
Proved |
Proved + Probable | |
Capital expenditures ($000) |
128,014 |
128,014 |
Net change in Future Development Capital ($000) |
(47,091) |
(131,400) |
Total capital ($000) |
80,923 |
(3,386) |
Total mboe, end of year |
255,057 |
366,106 |
Total mboe, beginning of year |
213,187 |
325,347 |
Production, mboe |
12,404 |
12,404 |
Reserve additions, mboe |
54,274 |
53,163 |
2016 F&D costs ($/boe) |
$1.49 |
$(0.06) |
2015 F&D costs ($/boe) |
$5.22 |
$4.65 |
Three-year average F&D costs ($/boe) |
$4.53 |
$2.76 |
(1) |
F&D costs are calculated by dividing total capital by reserve additions during the applicable period. Total capital includes both capital expenditures incurred and changes in FDC required to bring the proved undeveloped and probable reserves to production during the applicable period. Reserve additions is calculated as the change in reserves from the beginning to the ending of the applicable period excluding production. |
(2) |
The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated FDC generally will not reflect total finding and development costs related to reserves additions for that year. Changes in forecast FDC occur annually as a result of development activities, acquisition and disposition activities and capital cost estimates that reflect Sproule's best estimate of what it will cost to bring the proved undeveloped and probable reserves on production. |
(3) |
The change in FDC is primarily from lower future well costs which were partly offset by increases in facilities costs to include an upsized Glacier gas plant expansion to 400 mmcf/d and future infrastructure costs such as a frac water supply system, gas gathering system expansions and additional utilities. |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "guidance", "believe", "would" and similar expressions and include statements relating to, among other things, Advantage's anticipated future production from the Glacier Montney resource play and the expected timing thereof; Advantage's belief that its Glacier development will continue to be an industry leading North American low cost natural gas supply source; Advantage's 2017 through 2019 development plan, including estimated production per share growth and year-end total debt to trailing cash flow ratio; the expected timing of release of Advantage's 2016 financial and operational results; estimated production from Advantage's wells and the timing of achievement thereof; estimated number of drilling locations; Advantage's estimated fourth quarter and full year 2016 financial and operating results including production, royalties, operating costs, operating netback, capital expenditures and total debt including working capital; and Advantage's focus on maintaining operational and financial flexibility in conjunction with growth plans that generate profitability during lower commodity price cycles. In addition, statements relating to "reserves" are by their nature forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. The recovery and reserve estimates of Advantage's reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.sedar.com ("SEDAR") and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects.
Management has included the above summary of assumptions and risks related to forward-looking information above and in its continuous disclosure filings on SEDAR in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this news release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This press release contains a number of oil and gas metrics, including F&D, operating netback, recycle ratio, EUR, reserve replacement and reserve life index, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. Management uses these oil and gas metrics for its own performance measurements and to provide securityholders with measures to compare Advantage's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this news release, should not be relied upon for investment or other purposes.Operating netback is calculated by adding natural gas and liquids sales with realized gains on derivatives and subtracting royalty expense, operating expense and transportation expense. Recycle ratio is calculated by dividing Advantage's fourth quarter operating netback by the calculated F&D of the applicable year and expressed as a ratio. Reserve replacement is calculated by dividing reserves net volume additions by the current annual production and expressed as a percentage. Reserve life index is calculated by dividing the total volume of reserves by the fourth quarter production rate and expressed in years. Reserves per share is calculated as the total volume of reserves divided by the number of common shares issued and outstanding at year end. Reserves per debt-adjusted share assumes the issuance of additional common shares at the closing trading price on the TSX necessary to extinguish outstanding debt at year end and is calculated as the total volume of reserves divided by the sum of the number of common shares issued and outstanding at year end and the debt at year end divided by the Corporation's closing trading price on the TSX at year end.
The recovery and reserve estimates of reserves provided in this news release are estimates only, and there is no guarantee that the estimated reserves will be recovered. Actual reserves may eventually prove to be greater than, or less than, the estimates provided herein.
This press release discloses drilling locations in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations are derived from the Corporation's most recent independent reserves evaluation as prepared by Sproule as of December 31, 2016 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include total debt to trailing cash flow ratio and operating netback. Total debt to trailing cash flow ratio is calculated as bank indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Funds from operations is based on cash provided by operating activities, before expenditures on decommissioning liability and changes in non-cash working capital, reduced for finance expense excluding accretion. Operating netback is calculated as calculated by adding natural gas and liquids sales with realized gains on derivatives and subtracting royalty expense, operating expense and transportation expense. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures.
This press release and, in particular the information in respect of the Corporation's expected 2016 operating costs, capital expenditures, total debt and operating netback, and 2019 total debt to trailing cash flow ratio, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions, including the assumptions discussed above, and assumptions with respect to the costs and expenditures to be incurred by the Corporation, capital equipment and operating costs, foreign exchange rates, taxation rates for the Corporation, general and administrative expenses and the prices to be paid for the Corporation's production. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the FOFI or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. However, because this information is highly subjective and subject to numerous risks including the risks discussed above, it should not be relied on as necessarily indicative of future results. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
Certain financial and operating results included in this news release including production, operating costs, operating netback, capital expenditures and total debt including working capital are based on unaudited estimated results. These estimated results are subject to change upon completion of the Corporation's audited financial statements for the year ended December 31, 2016, and changes could be material. Advantage anticipates filing its audited financial statements and related management's discussion and analysis for the year ended December 31, 2016 on SEDAR on March 2, 2017.
The following abbreviations used in this press release have the meanings set forth below:
bbls |
barrels |
bcfe |
bllion cubic feet equivalent |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
mcf |
thousand cubic feet |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
tcfe |
trillion cubic feet equivalent |
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, Jan. 18, 2017 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that our 2016 operating and financial results outperformed the Corporation's previously disclosed guidance targets. Fourth quarter production, 2016 annual production, operating costs and cash flow were at or exceeded the higher end of guidance reinforcing our industry leading efficiencies, operational expertise and the exceptional quality of Advantage's Glacier Montney resource play.
Fourth quarter 2016 production was up 42% to a record 221 mmcfe/d (36,833 boe/d), representing production growth per share of 32% compared to the same period in 2015 and up from 215 mmcfe/d during the third quarter of 2016. Annual 2016 production was up 44% and 36% on a per share basis to 203 mmcfe/d (33,833 boe/d). Liquids production was up 494% on an annual basis as compared to 2015 and averaged 949 bbls/d (75% C5+) in the fourth quarter of 2016, slightly lower than the third quarter of 2016 due to Pembina Pipeline Corporation's planned maintenance in October. The Corporation's strategy to maintain excess Montney well productivity and to retain available processing capacity at its 100% owned Glacier gas plant provided operational flexibility to capitalize on strengthening gas prices and to offset TransCanada Pipeline Limited's ("TCPL") sales gas transportation restrictions during the fourth quarter of 2016.
Operating costs in the fourth quarter of 2016 were reduced by 37% to a record low of $0.22/mcfe ($1.32/boe) and reduced on an annual basis by 25% to $0.27/mcfe ($1.62/boe) compared to the same periods of 2015. This outstanding achievement was made possible by Advantage's continued focus on operational excellence and through the dedicated efforts of our Montney team.
Strong cash flow growth resulted in $39 million of surplus cash (funds from operations less capital expenditures) during 2016. During the fourth quarter of 2016 Advantage's operating netback of $2.83/mcfe ($16.98/boe) generated a 73% increase in cash flow to $55 million and a 58% increase in cash flow per share to $0.30 as compared to the same quarter of 2015. Annual cash flow was up 35% to $167 million and up 28% on a per share basis to $0.92. Capital spending during the fourth quarter of 2016 was $30 million and $128 million for 2016 resulting in year-end total debt of $159 million (includes working capital deficit) and a year-end total debt to 2016 cash flow of approximately 1.0x. These achievements were attained despite an average daily AECO natural gas price of $2.11/mcf during 2016.
(References to 2016 operational and financial results are estimates only and have not been reviewed or audited by our independent auditor. Advantage is expected to release its fourth quarter and audited year-end results after markets close on March 2, 2017 which results will include additional information)
Strong Well Results, Available Plant Capacity, 100% Firm Service and Additional Montney Land Acquisitions Sets the Foundation for 2017 Growth and Beyond
In December 2016, four Montney wells from our recently completed eight well pad were brought on-production (please refer to the Advantage press release dated October 12, 2016). These four wells demonstrated exceptional results with restricted individual well production rates ranging from 8.5 to 12.5 mmcf/d after one month of continuous production. Of particular note is that these four wells are still substantially rate restricted to limit sand flow back with current flowing pressures ranging from 7,900 to 17,900 kpa, well above our average gas gathering system pressure of 3,000 kpa. Management estimates that these four wells could produce at a combined production rate of approximately 65 mmcf/d at our average gas gathering system pressure of 3,000 kpa.
Available processing capacity at Advantage's 100% owned Glacier gas plant was successfully utilized to offset TCPL sales gas pipeline restrictions during 2016 and particularly during the fourth quarter when firm service restrictions were more pronounced. Advantage's current raw gas processing capacity of 260 mmcf/d at our Glacier plant is expected to provide operational flexibility in support of our 2017 annual production sales target of 236 mmcfe/d. The Corporation's ongoing Glacier plant expansion project to increase processing capacity to 400 mmcf/d (66,670 boe/d) is progressing with major equipment orders secured. Contruction is anticipated to commence during the second half of 2017 with completion targeted by the second quarter of 2018. This expansion will provide Advantage with available plant capacity and operational flexibility through to and beyond 2019.
In conjunction with our three-year development plan to increase production to 316 mmcfe/d (52,670 boe/d) in 2019, Advantage has secured 100% firm transportation service from TCPL to match our annual production targets and has requested additional transportation service for continued growth beyond 2019.
During 2016, Advantage increased its Montney land holdings by 12% through the acquisition of 16 sections of new Montney lands (100% owned) through Alberta Government land sales and producer transactions. The acquired lands were high graded and targeted based on our geotechnical interpretation and purchased for a total cost of $6 million during the lower natural gas commodity price environment.
Commodity Risk Management Program Provides Downside Protection & Market Diversification
Advantage has hedged 45% of its 2017 forecast natural gas production at an average AECO price of Cdn $3.19/mcf, 22% of 2018 estimated natural gas production at an average AECO price of Cdn $3.02/mcf and 18% of first quarter 2019 estimated natural gas production at an average AECO price of Cdn $3.00/mcf. Additionally, we have secured Henry Hub to AECO basis differentials of US$0.85/mmbtu on 25,000 mmbtu/d for calendar 2018 and 2019 to diversify our natural gas markets.
We believe taking a disciplined approach to managing commodity price risk for 2018 and beyond will be prudent as supply and demand fundamentals are expected to remain volatile.
The Corporation's operational flexibility combined with its strong balance sheet, Montney leading low cost structure and commodity risk management program provides a solid foundation for Advantage's future growth plans which are anticipated to provide strong investment returns. We look forward to reporting on our progress as we continue to advance the Corporation's Montney development program.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, estimates of calendar 2016 surplus cash flow; 2016 operating costs, operating netbacks, cash flow per share and year-end 2016 total debt to cash flow; references to Glacier plant expansion, production targets for 2017 and beyond and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; anticipated number of frac stages per well; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will continue to have credit available under its credit facility; available pipeline capacity; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; that the Corporation will be able to drill, complete and tie-in wells in the manner, on the timing and at the cost described herein; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the year ended December 31, 2017 are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2017, Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2017 expected drilling and completion activities and available pipeline capacity.
Management has included the above summary of assumptions and risks related to forward-looking information provided above and in its continuous disclosure documents filed on Sedar in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. The forward-looking statements contained herein are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
References in this press release to production test rates, initial test production rates, and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for Advantage. A pressure transient analysis or well-test interpretation has not been carried out in respect of all wells. Accordingly, the Corporation cautions that the test results should be considered to be preliminary.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"), including total debt to trailing cash flow ratio. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit, divided by funds from operations for the prior twelve month period. Management believes that such financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures.
This press release and, in particular the information in respect of the Corporation's prospective annual cash flow, operating costs, corporate cash costs and debt to trailing cash flow, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
2017 Budget Includes 17% Production Growth,
Upsized Glacier Gas Plant Expansion to 400 MMCF/D &
$205 Million Capital Program
(TSX: AAV, NYSE: AAV)
CALGARY, Nov. 28, 2016 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to announce that its Board of Directors ("Board") has approved a 2017 capital budget and development plan estimates for 2018 and 2019. Advantage's 2017 through 2019 investment will continue with the profitable and sustainable growth of our industry leading low cost Montney natural gas supply. This development will be supported by the Corporation's future drilling inventory of 1,100 dry gas and liquids rich Montney locations at Glacier which will remain the primary focus of development through the next decade. Additionally, the strategic expansion of Advantage's 100% owned Glacier gas plant processing capacity has been upsized from 350 mmcf/d to 400 mmcf/d (66,670 boe/d) with construction planned to start in the second half of 2017. This will provide optionality for accelerated growth at Glacier and operational flexibility to process a broader spectrum of gas and liquids compositions from Advantage's Montney lands located at Valhalla, Wembley and Progress in the greater Glacier area.
Advantage's 2017 capital budget includes an investment of $205 million targeted to increase annual production by 17% to 236 mmcfe/d (39,333 boe/d). Annual 2017 funds from operations is estimated to grow 27% on a per share basis to $210 million based on an average daily natural gas price of AECO Cdn $2.95/mcf ($2.80/GJ) and the Corporation's current hedging positions. The upsized Glacier plant expansion has minimal impact on the Corporation's 2017 capital expenditure budget due to Advantage's proven expertise in cost efficient facilities engineering design, lower construction costs and fewer required wells to grow and maintain production compared to earlier estimates. As a result, the Corporation's increasing cash flow is expected to reduce the total debt to trailing cash flow to 0.8 times at year-end 2017.
The Corporation's 2017 through 2019 development plan is targeted to increase 2016 annual production by 56% (52% on a per share basis) to 316 mmcfe/d (52,670 boe/d) in 2019 or 16% on an average annual per share basis. Based on an average AECO daily natural gas price of $2.95/mcf ($2.80/GJ) over the 2017 through 2019 period, cash flow is expected to grow by 78% (74% on a per share basis) or 20% on an average annual per share basis. Surplus cash is anticipated to reduce estimated year-end 2016 total debt from approximately $165 million to $55 million at year-end 2019, resulting in a total debt to trailing cash flow ratio of 0.2 times. At an average AECO Cdn daily natural gas price of $3.50/mcf ($3.30/GJ), Advantage's strong cash margins could generate $230 million of cumulative surplus cash over the 2017 through 2019 period. Total capital expenditures over the development plan period is estimated at $625 million and includes the drilling of 83 Montney wells.
The Corporation believes that the 2017 through 2019 period will require Canadian natural gas producers to become more competitive in the North America natural gas market and Advantage's continuing focus on capital discipline, cost efficiencies, profitability and financial strength will remain key success factors in achieving strong investment returns.
2017 Budget & Guidance
Glacier outperformance reduces total capital expenditures. Significant technological improvements in drilling and completion efficiencies, shallower production declines, lower well costs and lower total corporate cash costs have reduced the Corporation's capital requirements. The Corporation's 2017 capital program is estimated at approximately $205 million with $83 million directed to facilities and infrastructure. This includes the Glacier gas plant expansion where $71 million of the total $90 million is anticipated to be spent in calendar 2017. Additional facilities expenditures of $12 million include investments to support ongoing growth and value generation such as expansion of the field gas gathering system, a water source system and connections into other sales pipelines. A total of 21 wells are planned to be drilled in 2017 with 24 new and standing wells completed to support 2018 growth. The 2017 capital and operating budget includes consideration for potential increases in industry and regulatory costs.
Well production type curves in all Montney layers at Glacier have been increased. The Upper and Lower Montney average well production type curves have been increased to a Management estimated initial 30 day average well production rate ("IP30") of 7.5 mmcf/d with a 2P estimated ultimate recovery ("EUR") per well of 7.5 Bcfe (previous IP30 of 7.2 mmcf/d and 2P EUR of 7.2 Bcfe). For planning purposes, in areas where top quartile well results are anticipated, an average production well type curve with an IP30 of 9 mmcf/d and a 2P EUR of 9 Bcfe has been utilized. In the Middle Montney, the average well production type curve estimates have been increased to an IP30 of 5 mmcf/d with a 2P EUR of 5 Bcfe (previous IP30 of 4.5 mmcf/d and 2P EUR of 4.5 Bcfe). The drill, complete, equip and tie-in ("DCET") well costs are projected to be $4.8 million for all Upper, Middle and Lower Montney wells with an average lateral length of 1,800 meters and 25 frac stages. The DCET cost for wells with longer laterals and increased frac stages are adjusted accordingly in the budget.
Advantage's total corporate cash costs are estimated to be $0.63/mcfe for 2017. Advantage anticipates its industry leading low cost structure will continue due to the Corporation's proven operational expertise and our 100% owned Glacier gas plant which provides highly efficient gas processing costs. The Glacier gas plant expansion to 400 mmcf/d includes additional processing units added to the existing gas plant infrastructure creating economies of scale with the use of common utility systems, maintenance procedures and equipment interchangeability.
Firm Transportation Service Secured. Advantage has secured firm service sales gas transportation on TransCanada Pipeline Limited's ("TCPL") Nova Gas Transmission System (Alberta) for 100% of its planned production targets from 2017 through 2019.
Advantage's hedging positions reduce cash flow volatility. The Corporation believes natural gas prices will remain volatile and continues to provide downside cash flow protection through future hedge positions. Advantage has hedged 45% of its 2017 forecast natural gas production at AECO Cdn $3.19/mcf, 22% of estimated 2018 natural gas production at AECO Cdn $3.02/mcf and 18% of estimated Q1 2019 natural gas production at AECO Cdn $3.00/mcf.
125 mmcf/d of completed standing well productivity is currently available to support Advantage's 2017 production target. The 125 mmcf/d of average first month productivity ("IP30") is based on 9 currently completed standing wells which will be utilized to support its target of 236 mmcfe/d in 2017. Additional wells will be drilled in the fourth quarter of 2016 to support production levels in the second half of 2017 and early 2018. Advantage's development cycles are planned such that the timing of capital expenditure to initial cash flow is based on large well pads (> 10 wells). This normally means our drilling programs are completed approximately 8 to 12 months in advance and well completions are undertaken such that a sufficient number of completed wells remain in inventory to provide operational flexibility and optionality for increasing growth.
Advantage's 100% owned Glacier gas plant has current processing capacity to support its 2017 production target and additional capacity in the future. The Glacier gas plant expansion to 400 mmcf/d is targeted to begin construction during the second half of 2017 with completion expected by the second quarter of 2018. Total liquids handling capacity will be increased to 6,800 bbls/d of propane plus ("C3+") liquids. Post expansion, Advantage will have additional raw gas processing capacity of approximately 120 mmcf/d to 80 mmcf/d in 2018 and 2019 respectively, to provide operational flexibility, accelerate growth or accommodate third party processing. The expanded Glacier gas plant capacity to 400 mmcf/d will also match our existing sales gas pipeline lateral capacity of 400 mmcf/d which connects to TCPL.
2017 Budget & Guidance
The table below provides calendar year estimates:
2017 | ||
Average Annual Production (mmcfe/d) |
230 to 240 | |
% Natural Gas |
96%(2) | |
Royalty Rate (%) |
4% to 6% | |
Operating Costs ($/mcfe) |
$0.23 to $0.28 | |
Liquids Transportation Costs ($/mcfe) |
$0.03 to $0.05(3) | |
Capital Expenditures ($ Million) |
$195 to $215 | |
# Net Wells to be Drilled |
21(4) |
(1) |
Based on an average AECO Cdn $2.95/mcf natural gas price for 2017 and Advantage's current hedge positions. |
(2) |
Natural gas liquids expected to be ~1,600 bbls/d, up 57% over 2016 |
(3) |
Based on liquids transportation costs. Sales gas transportation costs are deducted from revenue associated with Advantage's sales gas marketing contract. |
(4) |
All new wells will be used to support 2018 growth. |
Total cash costs (includes royalties, operating costs, liquids transportation, cash G&A, interest & other cash expenses) for 2017 are estimated to average approximately $0.63/mcfe.
Beyond 2017
Comments regarding 2018 and 2019 are Management estimates and are not Board approved budgets. Additional details are included in our updated Management presentation available on our website.
Based on AECO Cdn natural gas prices of $2.95/mcf ($2.80/GJ) for 2018 and 2019 and the Corporation's current hedging positions, Advantage's development plan includes a targeted 15% production increase in 2018 to an annual average production rate of 272 mmcfe/d (45,330 boe/d) and a 16% increase in 2019 annual average production to 316 mmcfe/d (52,670 boe/d). Cash flow per share is estimated to grow 12% to $1.27 in 2018 and 22% to $1.55 in 2019. Capital expenditures of $210 million are estimated to be required in 2018 and $210 million in 2019 with a total of 62 wells to be drilled at Glacier over the two years. The estimated year-end total debt to trailing cash flow is estimated to be 0.6 times and 0.2 times at year-end 2018 and 2019, respectively.
The 2017 through 2019 development plan is expected to generate 56% production growth or 52% on a per share basis and 74% cash flow growth per share over this period. The total capital required during this period is estimated to be $625 million and is fully funded through cash flow.
Future Development at Valhalla, Wembley and Progress. During the fourth quarter of 2016, three initial evaluation wells were brought on-production in our Valhalla property. These three Valhalla wells will be produced to continue recovering load fluid and may be shut-in periodically to gather additional evaluation data. These initial wells were drilled in 2014 and 2015 into two of the four Montney layers present at Valhalla. Two of the wells were drilled into the Upper Montney and one well drilled in the first layer of the Middle Montney. The wells confirmed the presence of liquids in the Upper Montney, compared to dry gas in the Upper Montney at Glacier, as well as liquids in the first layer of the Middle Montney. This is consistent with Advantage's interpretation based on geotechnical work undertaken in 2012 which indicated that each layer of the Montney stack at Valhalla could contain liquids. In the three initial Valhalla evaluation wells, the C3+ liquid content of up to 45 bbls/mmcf is estimated based on a shallow cut liquids recovery process with a condensate quality that spans the condensate to oil window in the Upper and first Middle Montney layers. Natural gas production rates of up to 3.5 mmcf/d are similar to the initial Middle Montney delineation wells at Glacier. We are encouraged with these initial findings and to optimize the productivity of future wells, frac design changes and lowering the pipeline operating pressure in the Valhalla gathering system will be undertaken. Additional geotechnical evaluation and delineation drilling is required to determine the extent and composition of the gas and liquids content in all four potential Montney development layers at Valhalla.
At Wembley, industry drilling activity has extended to the northeast of the Pipestone Montney property and is beginning to encroach within several kilometres of Advantage's lands. Similarly, at our Progress land block, several industry wells which indicate liquids rich production have been drilled on-trend. Advantage has included plans to drill an initial evaluation well at Wembley and Progress within the next 18 to 24 months.
Continuing Forward With Financial Discipline and Operational Flexibility
The exceptional quality of the Corporation's Glacier Montney asset, an industry leading low cost structure and 100% ownership of our facilities demonstrated strong investment returns at low commodity prices in the last three years of our development. Advantage believes that continuing with a disciplined approach will generate long term attractive returns for our shareholders and provides upside potential as a more favourable natural gas price environment could evolve in North America as demand growth continues. We look forward to reporting our continued progress and achievements as we develop our high quality Montney resource.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the design of Advantage's 2017 through 2019 development program; anticipated number of future drilling locations and the Corporation's focus on developing such locations including the timing thereof; the proposed expansion of Advantage's Glacier gas plant processing capacity, including the amount of such expansion, the anticipated timing that construction will start and be completed on the proposed expansion, the expected benefits to Advantage from such expansion and the anticipated costs of such expansion (including the anticipated timing of which such costs will be incurred); the Corporation's delineation drilling plans on its Montney lands located at Valhalla, Wembley and Progress and the effect of such drilling on initial development and processing, including the anticipated timing thereof; Advantage's 2017 capital program, including the amount thereof, the amount to be allocated to increase annual production and the amount to be directed to facilities and infrastructure; the Corporation's drilling plans for 2017, including the number of wells to be drilled and the timing of completion of certain wells; Advantage's anticipated annual production (including the percentage of natural gas production), royalty rates, operating costs, liquids transportation costs, annual cash flow, total debt to trailing cash flow ratio and total corporate cash costs for 2017; Advantage's anticipated annual production, annual cash flow per share and total debt to trailing cash flow ratio for 2018; the Corporation's anticipated annual production, annual cash flow per share, year-end total debt and total debt to trailing cash flow ratio for 2019; Advantage's estimated capital expenditures from 2017 to 2019 and anticipated drilling plans, including the number of Montney wells to be drilled in such period; expected increases in production in 2017, 2018 and 2019 resulting from Advantage's development plan; the Corporation's expectation that total capital required from 2017 to 2019 will be fully funded from cash flow; the Corporation's view that the 2017 through 2019 period will require Canadian natural gas producers to become more competitive in the North America natural gas market and the key factors to Advantage achieving strong investment returns; management generated type curves; Advantage's belief that its industry leading low cost structure will continue; Advantage's future hedging positions, its beliefs related to the volatility of natural gas prices and its belief that such hedging positions are expected to reduce cash flow volatility and provide downside cash flow protection; Advantage's belief that continuing with a disciplined approach will generate long term attractive returns for shareholders while preserving upside potential for future opportunities; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs, cash costs and liquids transportation costs; frac stages per well; lateral lengths per well; estimated EURs; DCET well costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and that the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the years ended December 31, 2017, 2018 and 2019 are expressed as anticipated average production over the calendar year. In determining anticipated production for the years ended December 31, 2017, 2018 and 2019 Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2017, 2018 and 2019 expected drilling and completion activities.
Management has included the above summary of assumptions and risks related to forward-looking information in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive.
These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This press release contains certain oil and gas metrics, including EUR, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon. EUR represents the 2P estimated ultimate recoverable conventional natural gas volumes per well assigned by the Corporation's internal non-independent qualified reserves evaluator in accordance with the Canadian Oil & Gas Evaluation Handbook.
This press release discloses 1,100 undeveloped future drilling locations in the following categories: (i) proved (244 locations); (ii) proved + probable (297 locations); and (iii) unbooked (803 additional locations). Proved locations and probable locations are derived from the Corporation's most recent independent reserves evaluation as prepared by Sproule Associates Limited as of December 31, 2015 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.
Certain type curves presented herein represent estimates of the production decline and ultimate volumes expected to be recovered from wells over the life of the well. The 7.5 mmcf/d IP (which represents the average 30 day initial production rate) and 7.5 Bcfe (which represents the ultimate volumes expected to be recovered from the wells over the life of the well based on the type curve) Upper and Lower Montney type curve and the 5 mmcf/d IP and 5 Bcfe Middle Montney type curve are management generated type curves based on a combination of historical performance of older wells and management's expectation of what might be achieved from future wells. The type curves represent what management thinks an average well will achieve. Individual wells may be higher or lower but over a larger number of wells management expects the average to come out to the type curve. Over time type curves can and will change based on achieving more production history on older wells or more recent completion information on newer wells. Other type curves presented herein, including the 9 mmcf/d IP and 9 Bcf Upper and Lower Montney type curve have been provided to demonstrate the economics associated with wells that could potentially have that type of productivity and recovery but do not represent management estimates of how such wells will actually perform.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include total debt to trailing cash flow ratio, funds from operations and total cash costs. Total debt to trailing cash flow ratio is calculated as bank indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Funds from operations is based on cash provided by operating activities, before expenditures on decommissioning liability and changes in non-cash working capital, reduced for finance expense excluding accretion. Total cash costs includes royalties, operating costs, liquids transportation, cash G&A, interest & other cash expenses. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
This press release and, in particular the information in respect of the Corporation's prospective cash flow debt to trailing cash flow ratio, total cash costs, operating costs, capital expenditures, annual cash flow and liquids transportation costs, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions, including the assumptions discussed above, and assumptions with respect to the costs and expenditures to be incurred by the Corporation, capital equipment and operating costs, foreign exchange rates, taxation rates for the Corporation, general and administrative expenses and the prices to be paid for the Corporation's production. Management does not have firm commitments for all of the costs, expenditures, prices or other financial assumptions used to prepare the FOFI or assurance that such operating results will be achieved and, accordingly, the complete financial effects of all of those costs, expenditures, prices and operating results are not objectively determinable. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. However, because this information is highly subjective and subject to numerous risks including the risks discussed above, it should not be relied on as necessarily indicative of future results. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
The following abbreviations used in this press release have the meanings set forth below:
bbls |
barrels |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
mcf |
thousand cubic feet |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
44% Production Growth & 27% Reduction in Total Corporate Cash Costs Drives Surplus Cash Flow
(TSX: AAV, NYSE: AAV)
CALGARY, Nov. 3, 2016 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that the Corporation's strategy to maintain a profitable and sustainable growth plan is demonstrated by its third quarter 2016 production per share and cash flow per share increases of 33% and 20%, respectively, while reducing Advantage's total debt by 37% since year-end 2015. Advantage's continued production growth with further improvements in its industry leading capital and operating efficiencies have generated year-to-date surplus cash flow of $14 million (funds from operations net of capital expenditures) including $9 million in the third quarter of 2016. The surplus cash flow has further reduced the Corporation's total debt to $184 million at the end of the third quarter of 2016, down from $294 million at year-end 2015. These accomplishments were achieved despite a 20% reduction in the average AECO daily natural gas price to Cdn $2.32/mcf compared to Cdn $2.90/mcf in the same period of 2015. Advantage estimates its annual surplus cash flow could grow to approximately $36 million by year-end 2016 based on current commodity prices, resulting in an estimated year-end 2016 total debt-to-trailing cash flow ratio of 1.0 times.
During the third quarter of 2016, production increased 44% to 215 mmcfe/d (35,760 boe/d) and total corporate cash costs were reduced 27% to $0.58/mcfe ($3.48/boe) which helped drive cash flow up 31% to $45.1 million ($0.24/share) as compared to the third quarter of 2015. Advantage's cash flow was also supported by realized hedging gains of $11.9 million during the third quarter of 2016.
Advantage's focus on operational excellence demonstrated by production outperformance of its Glacier Montney wells (please refer to our operational update released on October 12, 2016) and continued cost reductions further reinforces the Corporation's solid foundation for Advantage's announced expansion of its 100% owned Glacier gas plant to 350 mmcf/d (58,330 boe/d). Advantage anticipates disclosing development plan details for the 2017 to 2019 period before year-end 2016.
Third Quarter 2016 Operating and Financial Highlights
Production increased 44% to average 215 mmcfe/d (35,760 boe/d) including 468% growth in natural gas liquids to 1,205 bbls/d for the third quarter of 2016 as compared to the same period in 2015. The Corporation's 2016 annual production is expected to be within our previously announced Budget production guidance range of 190 to 210 mmcfe/d generating a year-on-year production growth of approximately 40% or 34% on a per share basis. Liquids production is expected to remain flat to slightly lower in the fourth quarter due to Pembina Pipeline Corporation's maintenance work in October 2016.
Cash flow (Funds from Operations) for the third quarter of 2016 was up 31% to $45.1 million or 20% on a per share basis to $0.24 per share. Cash netbacks for the three months ended September 30, 2016 were $2.29/mcfe ($13.74/boe) which represents 80% of the realized sales price, including hedging. Excluding hedging, positive cash flow of $33.2 million was realized on an average AECO daily natural gas price of Cdn $2.32/mcf demonstrating the economic resilience of Advantage's Montney development.
Total corporate cash costs were reduced to a record low of $0.58/mcfe in the third quarter of 2016 which is a 27% decrease compared to the same period of 2015. Total corporate cash costs includes royalties ($0.08/mcfe), operating costs ($0.25/mcfe), liquids transportation ($0.05/mcfe), cash general and administrative ($0.09/mcfe), and cash finance expense ($0.11/mcfe). Liquids transportation costs were up slightly during the third quarter of 2016 due to additional trucking costs resulting from wet weather conditions which are extending into the fourth quarter of 2016.
Total capital expenditures during the quarter were on-track at $36 million. Drilling operations resumed during the quarter on a six well pad, with five of these wells rig released at the end of the third quarter of 2016. As communicated in Advantage's October 12, 2016 operational update, eight previously drilled wells were completed and production tested in the third quarter of 2016. The remaining capital activity in the third quarter was invested in expanding our plant utilities for future processing capacity growth. A 16 well pad commenced drilling during the fourth quarter of 2016 with well completions planned to start on this pad by mid-year 2017. Wet weather conditions have delayed recent drilling and completions activities; however, Advantage anticipates minimal impacts to our fourth quarter 2016 plans.
Total debt (including working capital deficit) as of September 30, 2016 was $184 million or 46% drawn against Advantage's $400 million borrowing base Credit Facility. Third quarter cash flow exceeded capital expenditures by $9.5 million and resulted in a decrease in bank debt. Advantage estimates approximately $36 million of surplus cash flow could be realized for calendar 2016 resulting in a year-end 2016 total debt-to-trailing cash flow of approximately 1.0x based on current commodity prices for the balance of 2016.
Natural gas hedge positions extended into 2019. Advantage's hedging positions include an average 48% of forecast production for the fourth quarter of 2016 at an average AECO floor price of $3.56/mcf, 45% of forecast 2017 annual production at an average AECO floor price of $3.19/mcf, 22% of forecast 2018 annual production at an average AECO floor price of $3.02/mcf and 18% of forecast production for the first quarter of 2019 at an average AECO floor price of $3.00/mcf.
Consolidated Financial Statements and MD&A
The Corporation's unaudited interim consolidated financial statements for the three and nine months ended September 30, 2016 together with the notes thereto, and Management's Discussion and Analysis for the three and nine months ended September 30, 2016 have been filed on SEDAR and EDGAR and are available on the Corporation's website at http://www.advantageog.com.
Third Quarter 2016 Operating & Financial Summary
Three months ended |
Nine months ended | |||||||||||
Financial and Operating Highlights |
September 30 |
September 30 | ||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||
Financial ($000, except as otherwise indicated) |
||||||||||||
Sales including realized hedging |
$ |
56,697 |
$ |
44,980 |
$ |
143,937 |
$ |
122,400 | ||||
Funds from operations |
$ |
45,132 |
$ |
34,474 |
$ |
112,251 |
$ |
91,974 | ||||
per share(1) |
$ |
0.24 |
$ |
0.20 |
$ |
0.62 |
$ |
0.54 | ||||
Total capital expenditures |
$ |
35,640 |
$ |
39,234 |
$ |
97,971 |
$ |
137,379 | ||||
Working capital deficit (2) |
$ |
5,023 |
$ |
12,273 |
$ |
5,023 |
$ |
12,273 | ||||
Bank indebtedness |
$ |
178,971 |
$ |
285,707 |
$ |
178,971 |
$ |
285,707 | ||||
Basic weighted average shares (000) |
184,572 |
170,715 |
181,188 |
170,563 | ||||||||
Operating |
||||||||||||
Daily Production |
||||||||||||
Natural gas (mcf/d) |
207,332 |
147,574 |
191,970 |
135,104 | ||||||||
Liquids (bbls/d) |
1,205 |
212 |
903 |
146 | ||||||||
Total mcfe/d(3) |
214,562 |
148,846 |
197,388 |
135,980 | ||||||||
Total boe/d(3) |
35,760 |
24,808 |
32,898 |
22,663 | ||||||||
Average prices (including hedging) |
||||||||||||
Natural gas ($/mcf) |
$ |
2.71 |
$ |
3.25 |
$ |
2.52 |
$ |
3.27 | ||||
Liquids ($/bbl) |
$ |
45.58 |
$ |
45.43 |
$ |
46.19 |
$ |
45.16 | ||||
Cash netbacks ($/mcfe)(3) |
||||||||||||
Natural gas and liquids sales |
$ |
2.27 |
$ |
2.70 |
$ |
1.80 |
$ |
2.65 | ||||
Realized gains on derivatives |
0.60 |
0.58 |
0.86 |
0.65 | ||||||||
Royalty expense |
(0.08) |
(0.12) |
(0.02) |
(0.12) | ||||||||
Operating expense |
(0.25) |
(0.36) |
(0.29) |
(0.36) | ||||||||
Transportation expense |
(0.05) |
- |
(0.03) |
- | ||||||||
Operating netback |
2.49 |
2.80 |
2.32 |
2.82 | ||||||||
General and administrative |
(0.09) |
(0.11) |
(0.11) |
(0.15) | ||||||||
Finance expense |
(0.11) |
(0.20) |
(0.14) |
(0.20) | ||||||||
Other income |
- |
0.02 |
0.01 |
0.01 | ||||||||
Cash netbacks |
$ |
2.29 |
$ |
2.51 |
$ |
2.08 |
$ |
2.48 | ||||
(1) |
Based on basic weighted average shares outstanding. |
|||||||
(2) |
Working capital deficit includes trade and other receivables, prepaid expenses and deposits, and trade and other accrued liabilities. | |||||||
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to | |||||||
one barrel of liquids. |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things; the Corporation's expectation that its 2016 annual production will be within its previously announced budget production guidance range; the Corporation's expectation that liquids production will remain flat or slightly lower in the fourth quarter of 2016; Advantage's drilling plans, including timing of commencing drilling on a 16 well pad and anticipated timing of completions starting on such pad; Advantage's estimated year-end 2016 total net debt to trailing cash flow and anticipated annual surplus cash flow; the Corporation's hedging arrangements; anticipated timing of disclosing Advantage's development plan for the 2017 to 2019 period; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; Advantage's ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the year ended December 31, 2016 are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2016, Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2016 expected drilling and completion activities. Advantage has also assumed TCPL's northwest Alberta pipeline restrictions and maintenance activity level will result in minimal firm service restrictions and frequent interruptible service availability during the second half of 2016 based on the most recent information available.
Management has included the above summary of assumptions and risks related to forward-looking information provided above and in its continuous disclosure documents filed on Sedar in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. Forward-looking statements contained herein are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains certain oil and gas metrics, including cash netbacks and operating netbacks, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include funds from operations, cash netbacks, operating netbacks, surplus cash flow and total debt to cash flow ratio. Funds from operations is based on cash provided by operating activities, before expenditures on decommissioning liability and changes in non-cash working capital, reduced for finance expense excluding accretion. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Surplus cash flow represents the amount by which funds from operations exceeds net capital expenditures. Total debt to cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit (surplus) divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
This press release and, in particular the information in respect of the Corporation's prospective surplus cash flow and total debt to cash flow ratio, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
New 120 MMCF/D Eight Well Montney Pad Exceeds Expectations
Corporate Production Increased to 215 MMCFE/D (35,760 boe/d) and Total Corporate Cash Costs Reduced to $0.58/mcfe
(TSX: AAV, NYSE: AAV)
CALGARY, Oct. 12, 2016 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that during the third quarter of 2016, a new Glacier eight well Montney pad was completed and outperformed Management expectations with a combined initial production flow rate of 120 mmcf/d. This eight well pad was designed to evaluate increased frac stages, longer horizontal laterals and cost efficiencies related to continued optimization of our well operations and larger pad sizes specifically in the Lower and Middle Montney formations.
The Corporation's third quarter 2016 production increased 44% to 215 mmcfe/d (35,760 boe/d), representing production growth per share of 33% compared to the same period in 2015 and up from 210 mmcfe/d during the second quarter of 2016. Liquids production increased to an average 1,200 bbls/d (80% C5+) and is expected to remain flat to slightly lower in the fourth quarter due to Pembina Pipeline Corporation's planned maintenance work in October 2016.
Total corporate cash costs were reduced to a record low of $0.58/mcfe ($3.48/boe) from $0.79/mcfe ($4.74/boe) in the third quarter of 2015 and $0.59/mcfe ($3.54/boe) in the second quarter of 2016. The lower total corporate cash costs were led by a 31% reduction in operating costs to $0.25/mcfe from $0.36/mcfe in the third quarter of 2015 and from $0.30/mcfe in the second quarter of 2016. The lower third quarter 2016 per unit operating costs resulted from reduced water disposal costs, more efficient equipment maintenance procedures and higher plant throughput. Royalties increased during the third quarter of 2016 due to a 66% increase in the AECO daily natural gas price compared to the second quarter of 2016. Cash flow during the third quarter of 2016 was up 31% to $45 million and 20% on a per share basis to $0.24/share as compared to the same quarter of 2015. Capital spending during the third quarter was $36 million resulting in a total debt of $184 million at the end of the quarter. Advantage estimates approximately $40 million of surplus cash flow could be realized for calendar 2016 resulting in a year-end 2016 total debt-to-cash flow of approximately 1.0x based on current commodity prices for the balance of 2016.
(Please note that references to third quarter 2016 operational and financial results are estimates only and have not been reviewed or audited by our independent auditors. Advantage is expected to release its third quarter results after markets close on November 3, 2016 which will include additional data)
New 120 mmcf/d Eight Well Montney Pad at Glacier Surpasses Management Expectations
During the third quarter of 2016, an eight well pad located at 5-16-76-13W6 consisting of six Lower Montney ("LM") wells, one Middle Montney ("MM") well and one Upper Montney ("UM") well was completed and evaluated by producing each well in-line to our Glacier plant. Each of these eight wells were flowed for an average of 48 hours and resulted in a combined production rate of 120 mmcf/d based on an average flowing pressure of 11,182 kpa (1,623 psi). The eight wells on the 5-16 well pad are expected to be placed on-stream during the next three to six months at restricted rates to control the amount of frac sand flow-back and to evaluate longer term well performance.
Three of the six Lower Montney wells on the pad were drilled to an average horizontal lateral length of 2,583 meters (with the longest well at 2,880 meters) and were fracture stimulated with an average of 28 frac stages utilizing 60 tonnes of proppant per frac stage. The remaining three LM wells were drilled to evaluate the LM reservoir in the area located east of the 5-16 pad and the results confirmed exceptional reservoir quality. All six of the LM wells were produced in-line to the Glacier gas plant and demonstrated a combined initial production rate of 100 mmcf/d at an average flowing pressure of 11,782 kpa (1,710 psi) based on an average 42 hours of flow per well. The average drill, complete, equipping and tie-in ("DCET") cost of these six LM wells was $4.3 million per well based on an average length of 2,119 meters and 24 frac stages. Three of the wells were drilled to a shorter average lateral length of 1,656 meters for an average DCET cost of $3.7 million per well to evaluate longer term recovery and spacing in the LM formation. These costs compare against the previous year's LM wells which had an average DCET cost of $5.3 million per well at an average lateral length of 1,930 meters and 19 frac stages.
The liquids rich Middle Montney well on the eight well pad was drilled offsetting one of the first MM wells located at 103/1-16-76-13W6 that was completed in 2012. The new MM well was drilled to a lateral length of 2,502 meters and contained 26 frac stages with open hole packers compared to the previous 103/1-16 offset well which had a lateral length of 1,635 meters and 11 frac stages completed with a plug and perf system. The proppant loading in the new well was 60 tonnes per frac stage compared to the 103/1-16 well which was stimulated with 150 tonnes per frac stage. The initial production rate from this new well was 11.3 mmcf/d after 71 hours of in-line flow at a flowing pressure of 10,747 kpa (1,560 psi). This compares to an initial rate of 3.7 mmcf/d from the 103/1-16 well. The propane plus ("C3+") liquid content of the new MM well is estimated to be approximately 30 bbls/mmcf, consistent with earlier results in the western part of the Glacier land block. The DCET cost of this new MM well was $5.1 million and represents the third well drilled in this western area of Glacier and confirms additional MM reservoir potential with improved capital efficiencies.
Management estimates this new 5-16 eight well pad alone will be sufficient to offset declines until the end of Q2 2017. A new 16 well pad commenced drilling in October and will be completed during the second half of 2017 to support production growth and to offset normal declines. The recent frac design changes and well results are being incorporated into our forecast model as we finalize plans for our next three year development period. Advantage anticipates providing updated development plan information before year-end 2016 allowing us to gather additional well production performance.
Standing Well Productivity and Plant Capacity Provides Operational Flexibility for Upcoming Winter Season
The Corporation is well positioned to increase production without incurring incremental capital costs and per unit operating costs in 2016 during this upcoming winter season. Advantage is able to immediately respond to improving natural gas prices by accessing its current surplus production capability of approximately 180 mmcf/d from 12 standing completed wells and additional processing capacity available at the Corporation's 100% owned Glacier gas plant.
Commodity Hedging Positions Provide Downside Protection
For the balance of 2016, approximately 48% of our production is hedged at an average AECO price of Cdn $3.56/mcf. Advantage has hedged 41% of its estimated 2017 annual production at an average AECO price of Cdn $3.19/mcf and 17% of estimated 2018 annual production at an average AECO price of Cdn $3.03/mcf. We anticipate increasing our future hedge positions if natural gas prices continue to rise, reflecting higher demand through the upcoming winter season.
The Corporation's operational flexibility combined with its strong balance sheet, Montney leading low cost structure and commodity hedging program provides a solid foundation for Advantage's previously announced expansion of its 100% owned Glacier gas plant to 350 mmcf/d (58,330 boe/d) which is expected to commence construction during the second half of 2017. We look forward to reporting on our progress as we continue to advance the Corporation's Glacier Montney development program.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the expectation that liquids production will remain flat to slightly lower in the fourth quarter due to Pembina Pipeline Corporation's planned maintenance work in October 2016; expectations of calendar 2016 surplus cash flow and year-end 2016 total debt to cash flow; the expected timing for bringing the eight wells on the 5-16 well pad on-stream at restricted rates to control the amount of frac sand flow-back and evaluate longer term well performance; the expectation that the new 5-16 eight well pad alone will be sufficient to offset declines until the end of Q2 2017; the expectation that a new 16 well pad will commence drilling in October and will be completed during the second half of 2017 to support production growth and offset normal declines; the expectation that the recent frac design changes and well results will be incorporated into our forecast model as we finalize plans for our next three year development period; the expectation that Advantage will provide updated development plan information before year-end 2016; the anticipation that Advantage will increase its future hedge positions as natural gas prices could reflect an improved North American natural gas supply and demand balance through the winter season; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; anticipated number of frac stages per well; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will continue to have credit available under its credit facility; available pipeline capacity; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; that the Corporation will be able to drill, complete and tie-in wells in the manner, on the timing and at the cost described herein; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the year ended December 31, 2016 are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2016, Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2016 expected drilling and completion activities and available pipeline capacity.
Management has included the above summary of assumptions and risks related to forward-looking information provided above and in its continuous disclosure documents filed on Sedar in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. The forward-looking statements contained herein are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
References in this press release to production test rates, initial test production rates, and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for Advantage. A pressure transient analysis or well-test interpretation has not been carried out in respect of all wells. Accordingly, the Corporation cautions that the test results should be considered to be preliminary.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"), including total debt to trailing cash flow ratio. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit, divided by funds from operations for the prior twelve month period. Management believes that such financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures.
This press release and, in particular the information in respect of the Corporation's prospective annual cash flow, operating costs, corporate cash costs and debt to trailing cash flow, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
Cash Flow Up 34% From 68% Production Growth, Record Low Corporate Cash Costs and Hedging Gains Montney Land Holdings Increased
(TSX: AAV, NYSE: AAV)
CALGARY, Aug. 4, 2016 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report cash flow increased 34% to $36.9 million ($0.20/share) driven by a 68% increase in production to 210 mmcfe/d (35,048 boe/d), a 34% reduction in total corporate cash costs to $0.59/mcfe ($3.54/boe) and realized hedging gains of $20.0 million during the second quarter of 2016. Despite a 47% reduction in AECO daily natural gas prices to Cdn $1.40/mcf, the Corporation generated $19.3 million of free cash flow above capital expenditures and reduced bank debt by $8.2 million. These achievements were made possible by the continuing production outperformance of our Glacier Montney wells and structural reductions in both total well capital costs and operating costs (please refer to our operational update released on July 6, 2016).
The Corporation increased its Montney land holdings to 150 net sections (96,000 net acres) from the acquisition of 12 high-graded net sections (100% working interest) during the first half of 2016 for a total cost of $5.8 million. Eleven of the 12 new sections were acquired through Crown land sales. At Glacier, seven new sections were added, which have immediate reserves recognition and drilling potential as they lie adjacent to existing lands containing wells previously drilled into multiple Montney layers. Management estimates that the seven newly acquired Glacier sections may contain in excess of 15 drilling locations per section which increases the total number of future drilling locations at the Corporation's Glacier property by 10% to over 1,100 locations. The remaining five new sections, which are anticipated to also contain multi-layer production potential, were acquired to increase our Montney land holdings at Valhalla and Wembley. In conjunction with Advantage's organic growth plans, the Corporation will continue to remain highly selective and opportunistic as it reviews Montney land and business opportunities to maintain its strategy of profitable and sustainable growth.
Looking forward, Advantage is well positioned with strong operational and financial flexibility to immediately increase production during the second half of 2016 without incurring additional capital and per unit operating costs should natural gas prices continue to strengthen. The Corporation's second quarter achievements combined with its current standing inventory of 22 wells (8 completed and 14 uncompleted) and completion of its engineering design to expand the Glacier gas plant to 350 mmcfe/d (58,330 boe/d), with construction beginning in the second half of 2017, continues to advance Advantage's next chapter of growth.
Second Quarter 2016 Operating and Financial Highlights
Production increased 68% to average 210.3 mmcfe/d (35,048 boe/d) including 867% growth in natural gas liquids to 1,083 bbls/d for the second quarter of 2016 as compared to the same period in 2015. The Corporation's 2016 annual production is expected to be within our previously announced Budget production guidance range of 190 to 210 mmcfe/d generating a year-on-year production growth of approximately 40% or 34% on a per share basis.
Cash flow (Funds from Operations) for the second quarter of 2016 was up 34% to $36.9 million or 25% on a per share basis to $0.20 per share. Cash netbacks for the three months ended June 30, 2016 were $1.92/mcfe ($11.52/boe) which represents 81% of the realized sales price, including hedging. Excluding hedging, positive cash flow of $16.9 million was realized despite an average AECO daily natural gas price of Cdn $1.40/mcf demonstrating the economic resilience of Advantage's Montney development.
Total corporate cash costs were reduced to a corporate record low of $0.59/mcfe in the second quarter of 2016 which is a 34% decrease compared to the same period of 2015. Total corporate cash costs includes royalties ($0.03/mcfe), operating costs ($0.30/mcfe), liquids transportation ($0.03/mcfe), cash general and administrative ($0.10/mcfe), and finance expense ($0.13/mcfe). Additionally, the Alberta government's annual gas cost allowance review recognized a positive recovery of $2.1 million for 2015 during the second quarter.
Total capital expenditures during the quarter were on-track at $18 million. Approximately 78% of the capital invested during the quarter was allocated to complete the expansion of Advantage's sales gas pipeline takeaway capacity to 400 mmcf/d from its Glacier gas plant to TransCanada Pipeline Limited's ("TCPL") main northwest Alberta sales pipeline, installation of additional acid gas capacity and a backup inlet compressor for future operational needs. Capital expenditures are estimated to be $125 million for the 2016 calendar year, including new land acquisitions during the first half of this year.
Total debt (including working capital surplus) as of June 30, 2016 was $194 million or 49% drawn against Advantage's $400 million borrowing base Credit Facility. Second quarter cash flow exceeded capital expenditures by $19.3 million and resulted in a decrease in bank debt. Advantage's year-end 2016 total debt to trailing cash flow is estimated to be 1.0 times should AECO natural gas prices average Cdn $2.50/mcf during the second half of 2016.
Strong multi-year natural gas hedge positions in place to support future development. Advantage's hedging positions include an average 50% of forecast annual production for the second half of 2016 at an average AECO floor price of $3.56/mcf, 41% of forecast 2017 annual production at an average AECO floor price of $3.19/mcf and 17% of forecast 2018 annual production at an average AECO floor price of $3.03/mcf.
Consolidated Financial Statements and MD&A
The Corporation's unaudited interim consolidated financial statements for the three and six months ended June 30, 2016 together with the notes thereto, and Management's Discussion and Analysis for the three and six months ended June 30, 2016 have been filed on SEDAR and EDGAR and are available on the Corporation's website at http://www.advantageog.com.
Second Quarter 2016 Operating & Financial Summary
Three months ended |
Six months ended | |||||||||||
Financial and Operating Highlights |
June 30 |
June 30 | ||||||||||
2016 |
2015 |
2016 |
2015 | |||||||||
Financial ($000, except as otherwise indicated) |
||||||||||||
Sales including realized hedging |
$ |
45,615 |
$ |
37,429 |
$ |
87,240 |
$ |
77,420 | ||||
Funds from operations |
$ |
36,883 |
$ |
27,571 |
$ |
67,119 |
$ |
57,500 | ||||
per share(1) |
$ |
0.20 |
$ |
0.16 |
$ |
0.37 |
$ |
0.34 | ||||
Total capital expenditures |
$ |
17,595 |
$ |
19,437 |
$ |
62,331 |
$ |
98,145 | ||||
Working capital deficit (surplus)(2) |
$ |
(525) |
$ |
16,046 |
$ |
(525) |
$ |
16,046 | ||||
Bank indebtedness |
$ |
194,028 |
$ |
277,322 |
$ |
194,028 |
$ |
277,322 | ||||
Basic weighted average shares (000) |
184,477 |
170,667 |
179,478 |
170,485 | ||||||||
Operating |
||||||||||||
Daily Production |
||||||||||||
Natural gas (mcf/d) |
203,791 |
124,299 |
184,204 |
128,765 | ||||||||
Liquids (bbls/d) |
1,083 |
112 |
750 |
112 | ||||||||
Total mcfe/d(3) |
210,289 |
124,971 |
188,704 |
129,437 | ||||||||
Total boe/d(3) |
35,048 |
20,829 |
31,451 |
21,573 | ||||||||
Average prices (including hedging) |
||||||||||||
Natural gas ($/mcf) |
$ |
2.18 |
$ |
3.27 |
$ |
2.41 |
$ |
3.28 | ||||
Liquids ($/bbl) |
$ |
52.67 |
$ |
47.91 |
$ |
46.69 |
$ |
44.90 | ||||
Cash netbacks ($/mcfe)(3) |
||||||||||||
Natural gas and liquids sales |
$ |
1.34 |
$ |
2.53 |
$ |
1.53 |
$ |
2.62 | ||||
Realized gains on derivatives |
1.04 |
0.76 |
1.01 |
0.68 | ||||||||
Royalty (expense) recovery |
0.08 |
(0.11) |
0.01 |
(0.12) | ||||||||
Operating expense |
(0.30) |
(0.37) |
(0.32) |
(0.36) | ||||||||
Transportation expense |
(0.03) |
- |
(0.02) |
- | ||||||||
Operating netback |
2.13 |
2.81 |
2.21 |
2.82 | ||||||||
General and administrative |
(0.10) |
(0.19) |
(0.11) |
(0.18) | ||||||||
Finance expense |
(0.13) |
(0.22) |
(0.15) |
(0.20) | ||||||||
Other income |
0.02 |
0.01 |
0.01 |
0.01 | ||||||||
Cash netbacks |
$ |
1.92 |
$ |
2.41 |
$ |
1.96 |
$ |
2.45 | ||||
(1) |
Based on basic weighted average shares outstanding. |
|||||||||
(2) |
Working capital deficit (surplus) includes trade and other receivables, prepaid expenses and deposits, and trade and other accrued liabilities. |
|||||||||
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to |
|||||||||
one barrel of liquids. |
||||||||||
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, managements estimates of drilling locations on the seven newly acquired Glacier sections, anticipated multi-layer production potential of five other newly acquired sections, and aggregate estimated number of drilling locations; the Corporation's plans to review Montney land and business opportunities to maintain its strategy of profitable and sustainable growth; Advantage's expansion of its Glacier gas plant processing capacity and anticipated processing capacity as a result thereof; Advantage's belief that it is well positioned with strong operational and financial flexibility to immediately increase production during the second half of 2016 without incurring additional capital and per unit operating costs should natural gas prices continue to strengthen; the Corporation's expectation that its 2016 annual production will be within its previously announced budget production guidance range; capital expenditures for the 2016 calendar year, including the estimated amount thereof; Advantage's estimated year-end 2016 total net debt to trailing cash flow; the Corporation's hedging arrangements; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; Advantage's ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the year ended December 31, 2016 are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2016, Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2016 expected drilling and completion activities. Advantage has also assumed TCPL's northwest Alberta pipeline restrictions and maintenance activity level will result in minimal firm service restrictions and frequent interruptible service availability during the second half of 2016 based on the most recent information available.
Management has included the above summary of assumptions and risks related to forward-looking information provided above and in its continuous disclosure documents filed on Sedar in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. Forward-looking statements contained herein are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains certain oil and gas metrics, including cash netbacks and operating netbacks, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon.
This press release discloses over 1,100 undeveloped future drilling locations in the following categories: (i) proved (244 locations); (ii) proved + probable (297 locations); and (iii) unbooked (more than 803 additional locations). Proved locations and probable locations are derived from the Corporation's most recent independent reserves evaluation as prepared by Sproule Associates Limited as of December 31, 2015 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Of the 15 drilling locations per section estimated by Management on the seven newly acquired Glacier sections identified herein, all are unbooked locations. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include funds from operations, operating netbacks and total debt to trailing cash flow ratio. Funds from operations is based on cash provided by operating activities, before expenditures on decommissioning liability and changes in non-cash working capital, reduced for finance expense excluding accretion. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit (surplus) divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
This press release and, in particular the information in respect of the Corporation's prospective cash flow debt to trailing cash flow ratio, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, July 6, 2016 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that its accomplishments during the second quarter of 2016 have further strengthened the foundation for the Corporation's next chapter of growth to 350 mmcfe/d (58,330 boe/d). During the second quarter, production growth exceeded expectations and reduced operating costs contributed to record low total corporate cash costs. Production performance from key wells, which contained the latest modified frac designs, demonstrated top quartile rates and Advantage's Glacier gas plant was operated near design throughput allowing us to confirm equipment capability. Advantage's sales gas pipeline loop was commissioned, increasing total take-away capacity to TCPL to 400 mmcf/d and back-up wells for water disposal and acid gas injection to support the next Glacier plant expansion were completed. Additionally, we have secured a base level of increasing natural gas firm service transportation commitments which total 293 mmcf/d by early 2019.
The Corporation is well positioned to increase production significantly without incurring incremental capital costs and per unit operating costs during the second half of 2016 should natural gas prices continue to strengthen. Advantage is able to immediately access its current surplus production capability of approximately 70 mmcf/d from 10 standing completed wells and approximately 50 mmcf/d of additional processing capacity available at the Corporation's 100% owned Glacier gas plant. An additional 8 of our 14 standing uncompleted wells will be completed and tied-in during the second half of this year as planned in our 2016 capital budget. These wells will support and grow production through to spring 2017. The Corporation's operational flexibility combined with its strong balance sheet, Montney leading low cost structure and strong commodity hedging program provides the foundation for Advantage's previously announced expansion of its 100% owned Glacier gas plant to 350 mmcf/d (58,330 boe/d).
Highlights during the second quarter of 2016, which demonstrate the Corporation's achievements, are included below: (Please note that references to second quarter 2016 operational and financial results are estimates only and have not been reviewed or audited by our independent auditors. Advantage is expected to release its second quarter results on August 4, 2016 which will include additional data).
Advantage's production during the second quarter of 2016 increased to 210 mmcfe/d (35,000 boe/d), 26% higher than the first quarter of 2016 and 68% higher than the same period of 2015 resulting in production per share growth of 56%.
Total natural gas liquids production increased 151% to average 1,050 bbls/day compared to the first quarter of 2016. The liquids are comprised of 80% condensate ("C5+") since Advantage continues to limit propane sales by re-injecting this product back into the sales gas stream and realizes a higher netback than extracting and selling propane due to its current low commodity price.
Operating costs during the second quarter of 2016 decreased 14% to $0.30/mcfe. Operating cost reduction initiatives included an additional water disposal well which reduced water handling costs during the second quarter. Natural gas liquids transportation costs were $0.03/mcfe during the quarter.
Total corporate cash costs reached a record low of $0.60/mcfe including royalties, operating costs, liquids transportation costs, cash G&A and financing costs.
The previously announced Glacier Gas Plant Expansion to 350 mmcf/d (58,330 boe/d) is on track with engineering design work nearing completion and regulatory application work underway. The expansion is expected to be completed by the second quarter of 2018.
Modified Completion and Frac Designs Improve Well Performance and Costs. Advantage's Glacier standing well inventory contains numerous wells which were designed to evaluate reduced frac spacing, frac ports and longer length laterals primarily in the Lower and Middle Montney where a relatively low amount of this resource has been booked as reserves in these layers. Additional completion and frac design changes in the Upper Montney will be further evaluated in the next drilling program.
In the Lower Montney, three recent wells brought on-production are demonstrating performance which is trending near management's estimated top quartile Lower Montney average well type curve with an initial 30 day average production rate ("IP30") of 9 mmcf/d compared to our Budget Lower Montney average well type curve with an IP30 of 7.2 mmcf/d. Of particular interest is our first Lower Montney well which was completed with a cemented port, ball-drop system with 37 frac ports, 20 frac stages, slickwater and 1,480 tonnes of proppant that is significantly outperforming Management expectations. The well began production on April 27, 2016 at 18 mmcf/d (3,000 boe/d) and has been restricted below 10 mmcf/d for frac sand flow back control. This well is currently producing at a restricted rate of 7 mmcf/d at 11 mpa and is estimated to be still capable of producing in excess of 12 mmcf/d. The frac port system contributed to reducing drill, complete and tie-in well costs from $5.4 to $5.0 million resulting in a well capital efficiency of $2,200/boe/d. In the second half of 2016, 5 new Lower Montney wells are expected to be brought on-production. Three of these wells contain lateral lengths averaging 2,500 meters with the longest lateral at 2,900 meters and up to 28 frac stages compared to our historical wells which contained an average lateral length of 1,800 meters and 18 frac stages.
In the liquids rich Middle Montney formation, four new wells are trending near management's estimated top quartile Middle Montney average well type curve with an IP30 of 6 mmcf/d compared to our Budget Middle Montney average well type curve of 4.5 mmcf/d. These wells contain an average of 20 frac stages compared to our 2013 wells which contained an average 15 frac stages. Two of these wells were drilled into the lowest layer of the Middle Montney which was previously un-drilled at Glacier. Both wells are tracking at least 25% above our average Middle Montney well type curve after producing for 180 and 90 days, respectively. There are no future undeveloped locations booked for this Middle Montney layer in Advantage's year end 2015 reserve report.
Well costs continue to improve. Advantage will commence drilling 13 new wells in July 2016 and total well costs (drill, complete, equip and tie-in) are expected to continue to improve. We estimate Lower Montney wells will average $5.1 million per well based on an average of 25 fracs stages per well, approximately $0.7 million lower than previously drilled wells in the Lower Montney. Middle Montney well costs are also estimated to be reduced by $0.7 million per well to approximately $5.4 million based on 25 frac stages.
Advantage has secured increasing levels of TransCanada Pipeline Limited ("TCPL") firm natural gas transportation service from 2016 to 2019 ranging between 95% to 105% of estimated future annual production. Currently, the Corporation has contracted a total of 293 mmcf/d of firm natural gas sales transportation service by early 2019. Advantage continues to evaluate the availability and timing of firm and interruptible natural gas transportation capacity and alternative options to determine the amount and timing of future firm service commitment volumes that it views as appropriate to preserve flexibility for future growth. Options for transportation and sales of associated liquids production through to 2019 are also being evaluated.
Advantage's interest costs will decrease by $0.4 million per year resulting from the Corporation's request to reduce its credit facility from $450 million to $400 million. Advantage's strong balance sheet and estimated capital requirements for future growth provides ample flexibility to reduce its current credit facility. Advantage's debt is estimated to be $194 million at the end of the second quarter resulting in a 50% draw against its revised credit facility and over $200 million of additional liquidity.
Should natural gas prices average AECO Cdn $2.50/mcf during the second half of 2016, Advantage estimates $25 million of surplus cash flow would be realized with a Year-end total Debt to trailing Cash flow of 1x. Improving natural gas prices and Advantage's attractive hedging program which includes 52% of 2016 annual production at an average AECO price of Cdn $3.62/mcf combined with its low cost structure is anticipated to generate cash flow in excess of its planned 2016 capital program of approximately $120 million. Advantage's hedging position has been increased to 36% of forecast 2017 annual production at an average AECO price of Cdn $3.24/mcf and 13% of forecast 2018 production at an average AECO price of Cdn $3.04/mcf. These hedge positions combined with our strong balance sheet provide additional financial flexibility to support the next significant expansion of Advantage's Glacier gas plant processing capacity to 350 mmcf/d planned to commence construction during the second half of 2017.
The Corporation's hedging program, industry leading low costs, improved capital efficiencies and strengthened balance sheet have already positioned Advantage with significant downside protection with flexibility to capitalize on improved natural gas prices which we anticipate will occur as North American natural gas supply and demand become better balanced in the future.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the Corporation's beliefe that it is well positioned with significant operational flexibility to increase production without incurring incremental capital costs and per unit operating costs during the second half of 2016 should natural gas prices continue to strengthen; Advantage's anticipated annual production for 2016, production growth for 2017, year end debt to trailing cash flow ratio for 2016, expected surplus cash flow, estimated debt as at June 30, 2016, cash costs and operating costs through 2016 (including royalties, liquids transportation costs, cash G&A and financing costs) and cash flow and capital expenditures for 2016, including the targeted amounts and timing of achievement thereof; expected increases in production in 2016 and 2017 resulting from Advantage's Glacier development plan; the Corporation's planned expansion of the Glacier gas plant processing capacity, the expected capacity, the status of the regulatory application and design work in relation thereto, the timing of commencement thereof and the anticipated timing of completion thereof; Advantage's drilling plans and anticipated results, including, the expected timing of completion of the Corporation's standing uncompleted wells, the effect of completion of additional wells on production growth through to spring 2017, anticipated well production rates, expected timing that certain new Lower Montney wells will be brought on-production, timing of commencement of drilling new wells in the Lower and Middle Montney and total well cost estimates related thereto, and expected reductions to Middle Montney well costs; the anticipated impact of continued operational efficiencies and lower service costs on reducing well costs; the Corporation's belief that its strong balance sheet, Montney leading low cost structure and strong commodity hedging program provides financial flexibility for Advantage's previously announced expansion of the Glacier gas plant; Advantage's plans to evaluate the availability and timing of firm and interruptible natural gas transportation capacity and alternative options, as well as options for transportation and sales of associated liquids production through to 2019; the Corporation's expectation that it's credit facility borrowing base will be reduced by the lenders resulting in a decrease in Advantage's interest costs, and the anticipated amount of such decrease; Advantage's expectation that improving natural gas prices and Advantage's hedging program and low cost structure will generate cash flow in excess of the Corporation's planned 2016 capital program, including the estimated amount thereof; the Corporation's belief that its hedging program, low costs, improved capital efficiencies and strengthened balance sheet have positioned Advantage with significant downside protection and flexibility to capitalize on improved natural gas prices; Advantage's belief that North American natural gas supply and demand will become better balanced in the future; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; anticipated number of frac stages per well; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the borrowing base under the Corporation's credit facility will be reduced to the amount anticipated; available pipeline capacity; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; that the Corporation will be able to drill, complete and tie-in wells in the manner and on the timing described herein; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the year ended December 31, 2016 are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2016, Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2016 expected drilling and completion activities and available pipeline capacity.
Management has included the above summary of assumptions and risks related to forward-looking information provided above and in its continuous disclosure documents filed on Sedar in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. The forward-looking statements contained herein are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Certain type curves referred to in this press release represent estimates of the production decline and ultimate volumes expected to be recovered from wells over the life of the well. 7.2 Bcfe Upper and Lower Montney Budget type curves and 4.5 Bcfe Middle Montney Budget type curves are management generated type curves based on a combination of historical performance of older wells and management's expectation of what might be achieved from future wells. The type curves represent what management thinks an average well will achieve. Individual wells may be higher or lower but over a larger number of wells management expects the average to come out to the type curve. Over time type curves can and will change based on achieving more production history on older wells or more recent completion information on newer wells.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
References in this press release to production test rates, initial test production rates, and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for Advantage. A pressure transient analysis or well-test interpretation has not been carried out in respect of all wells. Accordingly, the Corporation cautions that the test results should be considered to be preliminary.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"), including total debt to trailing cash flow ratio. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit, divided by funds from operations for the prior twelve month period. Management believes that such financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures.
This press release and, in particular the information in respect of the Corporation's prospective annual cash flow, operating costs, corporate cash costs and debt to trailing cash flow, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, May 26, 2016 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage") is pleased to announce that on May 26, 2016 it held its annual general meeting of shareholders (the "Meeting"). A total of 142,824,669 common shares (approximately 77.43% of the outstanding common shares) were represented at the Meeting in person or by proxy.
At the Meeting, shareholders approved the election of six nominees as directors of Advantage to serve until the next annual meeting of shareholders or until their successors are elected or appointed, with the number and percentage of common shares represented at the Meeting voting by way of ballot in favour or withheld from voting for the individual nominees as follows:
FOR |
WITHHELD | ||||||
Number |
Percentage |
Number |
Percentage | ||||
Stephen E. Balog |
133,196,188 |
99.12% |
1,187,171 |
0.88% | |||
Grant B. Fagerheim |
132,793,646 |
98.82% |
1,589,713 |
1.18% | |||
Paul G. Haggis |
133,181,516 |
99.11% |
1,201,843 |
0.89% | |||
Andy J. Mah |
133,621,018 |
99.43% |
762,341 |
0.57% | |||
Ronald A. McIntosh |
132,757,809 |
98.79% |
1,625,550 |
1.21% | |||
Jill T. Angevine |
133,180,524 |
99.10% |
1,202,835 |
0.90% |
For complete voting results, please see our Report of Voting Results available on SEDAR at www.sedar.com.
SOURCE Advantage Oil & Gas Ltd.
Production Growth, Record Low Cash Costs & Improved Glacier Well Results Generates Strong Cash Flow & Underpins 350 MMCF/D Plant Expansion Plan
(TSX: AAV, NYSE: AAV)
CALGARY, May 5, 2016 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report strong cash flow of $30.2 million or $0.17/share for the first quarter of 2016 supported by a 25% increase in production to 167 mmcfe/d (27,854 boe/d) and an 11% reduction in its total cash cost to a corporate record and industry leading low cost of $0.75/mcfe. Additionally, Advantage's financial strategy to reduce downside cash flow exposure through its ongoing hedging program generated a $14.7 million gain which is included in our first quarter results. These operational and financial achievements helped to maintain a comparable level of cash flow to the same period in 2015 despite a 33% reduction in AECO natural gas prices to Cdn $1.84/mcf.
During the first quarter of 2016, Advantage continued to achieve outperformance in its Glacier well results. In particular, one of our Lower Montney wells which included a new cemented port completion design with 37 frac ports and 20 frac stages significantly exceeded Management expectations by demonstrating an on-production rate of 18.3 mmcf/d (3,050 boe/d) and proved up another extension area of high quality Lower Montney reservoir at Glacier. This Lower Montney well was drilled, completed and tied-in at a cost of $5 million (10% less than budgeted) and confirmed additional opportunities to improve capital efficiencies as a result of advancing our drilling and completion technologies. Five other Lower Montney wells with an average of 21 frac stages were production tested during the quarter and demonstrated an average per well rate of 12.3 mmcf/d, exceeding Management expectations by 30% (see additional information in the Operational Update section below).
Advantage's plans to expand its 100% owned Glacier gas plant to increase processing capacity from 250 to 350 mmcf/d (58,330 boe/d) is progressing with design and regulatory application work underway. The Glacier "350" plant expansion is targeted for completion in the second quarter of 2018 to continue production growth through 2020. These plans are reinforced by our ongoing operational achievements and solid financial results which demonstrate the exceptional quality of our Glacier Montney resource.
Advantage continues to advance its Montney development at Glacier with a strategy to reduce downside cash flow exposure while retaining financial and operational flexibility to immediately capitalize on improvements in the natural gas price environment and organic growth opportunities. The Corporation's strong balance sheet and multi-year hedging program in conjunction with having readily available additional gas plant capacity and additional productivity from its 27 current standing wells provides flexibility to optimize investment returns for our shareholders.
First Quarter 2016 Operating and Financial Highlights
Production increased 25% to average 167.1 mmcfe/d (27,854 boe/d) for the first quarter of 2016 as compared to the same period in 2015. In April 2016 Glacier production increased a further 20% from the prior quarter to a record 200 mmcfe/d (33,300 boe/d). The Corporation's 2016 annual production is expected to be within our previously announced Budget production guidance range of 190 to 210 mmcfe/d, resulting in year on year production growth of 40%.
Funds from operations for the first quarter of 2016 was $30.2 million or $0.17 per share. Cash netbacks for the three months ended March 31, 2016 was $1.99/mcfe ($11.94/boe) which represents 73% of the realized sales price, including hedging. Funds from operations were supported by increased production, lower costs and a realized hedging gain of $14.7 million.
Total cash costs were reduced to a corporate record low of $0.75/mcfe in the first quarter of 2016 which is an 11% decrease compared to the same period of 2015. Total cash costs include royalties ($0.07/mcfe), operating expense ($0.35/mcfe), transportation expense for liquids ($0.01/mcfe), general and administrative expense ($0.13/mcfe), and finance expense ($0.19/mcfe). An additional water disposal well was commissioned in March 2016 to reduce water handling costs and when combined with other ongoing cost initiatives, we anticipate additional operating cost savings could be realized during the latter half of 2016.
Capital expenditures during the quarter were on-track at $45 million. This included $32 million (71%) invested to expand Advantage's sales gas pipeline takeaway capacity to 400 mmcf/d from its Glacier gas plant to TransCanada Pipeline Limited's ("TCPL") main northwest Alberta sales pipeline, to increase its raw gas gathering system capacity and to install back-up plant utilities. The remaining expenditures in the quarter were directed to completion operations on 7 previously cased wells. Capital expenditures are targeted to be $58 million during the first half of 2016 and $120 million for the full year.
Total debt (including working capital deficit) as of March 31, 2016 was $213 million or 47% drawn against Advantage's $450 million borrowing base Credit Facility providing ample financial flexibility to support future development. Advantage's year-end 2016 total debt to trailing cash flow is estimated to be 1.2 times and 1.5 times based on average annual AECO natural gas prices of Cdn $2.00/mcf and Cdn $1.50/mcf respectively, including the Corporation's hedges.
Strong multi-year natural gas hedge positions in place to support future development. Advantage's hedging positions include an average 52% of forecast annual production for 2016 at an average AECO floor price of $3.62/mcf, 36% of forecast 2017 annual production at an average AECO floor price of $3.24/mcf and 15% of forecast 2018 annual production at average AECO floor price of $3.04/mcf.
Operational Update
Lower Montney Wells Exceed Expectations
A Lower Montney well located in the central area of Glacier was drilled to a lateral length of 2,083 meters and was completed with a cemented port, ball-drop system with 37 frac ports (45 meter spacing) and 20 stages, slickwater and 1,480 tonnes of proppant. This Lower Montney well has been standing since December 2015 and was recently brought on production. After four days of production, the well was producing at a restricted rate of 18.3 mmcf/d (3,050 boe/d) and at a flowing pressure of 7 mpa, above its tested rate of 12.4 mmcf/d. This Lower Montney well will be restricted below 10 mmcf/d to control the volume of frac sand flowback during its initial production period to match the design of our standard wellsite facilities. The longer term production behavior will be evaluated to assess the change in frac design but the initial results are encouraging. The total drill, complete and tie-in cost of $5 million for this Lower Montney well results in an estimated 30 day average initial production rate ("IP30") well capital efficiency of $2,220/boe/d. Additionally, this well proves up an expanded area of top decile Lower Montney well productivity at Glacier.
During the first quarter of 2016, five other Lower Montney wells were production tested at Glacier. After an average flow period of 57 hours, the average per well final production test rate was 12.3 mmcf/d normalized to our average gas gathering system flowing pressure of 3,000 kpa (435 psi). At the average final production test pressure of 11.2 mpa (1,624 psi) the average production test rate was 10.2 mmcf/d. These wells included an average of 21 frac stages and exceeded Management's final production test rate expectations by 30%.
For the balance of 2016, additional wells which contain a combination of higher frac stages, cemented ports and longer laterals will be brought on-production and compared against offsetting older wells to evaluate the long term production and reserve impacts of drilling and completion technology changes at Glacier.
Glacier "350" Gas Plant Expansion
Design and regulatory application work has commenced on Advantage's planned expansion of its 100% owned Glacier gas plant processing capacity from 250 to 350 mmcf/d (58,330 boe/d). The expansion will be undertaken at the existing Glacier gas plant site with a preliminary cost estimate of $75 million. The existing gas plant capacity of 250 mmcf/d will provide sufficient processing throughput to accommodate growth plans through 2017. The plant expansion to 350 mmcf/d is targeted for completion in the second quarter of 2018 and will accommodate growth plans through 2020. Options to accelerate this expansion project while maintaining industry leading capital efficiencies will also be evaluated.
Modernized Royalty Framework Impact
The Alberta government has now substantially completed the new Modernized Royalty Framework. The new royalty framework partially emulates a revenue minus cost royalty structure and will be effective for wells spud on or after January 1, 2017 with existing wells continuing to operate under the previous royalty framework for a ten-year period. The new royalty framework is expected to incentivize low cost producers with higher productivity wells which will continue to benefit Advantage. We have reviewed the new framework formulas and estimate that at natural gas prices up to AECO $4.00/mcf, the impact on the economic returns for our average Upper and Lower Montney wells are insignificant while the economic returns for our average Middle Montney wells are slightly improved. Advantage will continue to evaluate and optimize the impact of drilling and completion design changes on royalties and economics in respect of the Modernized Royalty Framework.
Consolidated Financial Statements and MD&A
The Corporation's unaudited interim consolidated financial statements for the three months ended March 31, 2016 together with the notes thereto, and Management's Discussion and Analysis for the three months ended March 31, 2016 have been filed on SEDAR and with the SEC and are available on the Corporation's website at http://www.advantageog.com. Upon request, Advantage will provide a hard copy of any financial reports free of charge.
Appendix – First Quarter 2016 Operating & Financial Summary
Three months ended |
||||||||
Financial and Operating Highlights |
March 31 |
|||||||
2016 |
2015 |
|||||||
Financial ($000, except as otherwise indicated) |
||||||||
Sales including realized hedging |
$ |
41,625 |
$ |
39,991 |
||||
Funds from operations |
$ |
30,236 |
$ |
29,929 |
||||
per share(1) |
$ |
0.17 |
$ |
0.18 |
||||
Total capital expenditures |
$ |
44,736 |
$ |
78,708 |
||||
Working capital deficit(2) |
$ |
10,666 |
$ |
40,552 |
||||
Bank indebtedness |
$ |
202,538 |
$ |
261,241 |
||||
Basic weighted average shares (000) |
174,479 |
170,301 |
||||||
Operating |
||||||||
Daily Production |
||||||||
Natural gas (mcf/d) |
164,618 |
133,281 |
||||||
Liquids (bbls/d) |
418 |
112 |
||||||
Total mcfe/d(3) |
167,126 |
133,953 |
||||||
Total boe/d(3) |
27,854 |
22,326 |
||||||
Average prices (including hedging) |
||||||||
Natural gas ($/mcf) |
$ |
2.70 |
$ |
3.30 |
||||
Liquids ($/bbl) |
$ |
31.21 |
$ |
41.86 |
||||
Cash netbacks ($/mcfe)(3) |
||||||||
Natural gas and liquids sales |
$ |
1.77 |
$ |
2.71 |
||||
Realized gains on derivatives |
0.97 |
0.61 |
||||||
Royalties |
(0.07) |
(0.13) |
||||||
Operating expense |
(0.35) |
(0.35) |
||||||
Transportation expense |
(0.01) |
- |
||||||
Operating netback |
2.31 |
2.84 |
||||||
General and administrative |
(0.13) |
(0.17) |
||||||
Finance expense |
(0.19) |
(0.19) |
||||||
Cash netbacks |
$ |
1.99 |
$ |
2.48 |
||||
(1) |
Based on basic weighted average shares outstanding. |
|||||
(2) |
Working capital deficit includes trade and other receivables, prepaid expenses and deposits, and trade and other accrued liabilities. |
|||||
(3) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to |
|||||
one barrel of liquids. |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, the potential for future improvements in capital efficiencies resulting from continued drilling and completion technology advances at Glacier; Advantage's expansion of its Glacier gas plant processing capacity, including the expected timing, estimated costs and anticipated processing capacity as a result thereof; the Corporation's strategy to reduce downside cash flow exposure while retaining financial and operational flexibility to immediately capitalize on improvements in the natural gas price environment and organic growth opportunities; the anticipated effect of a strong balance sheet, multi-year hedging program, additional gas plant capacity and additional productivity on Advantage's ability to provide investment returns for shareholders; Advantage's anticipated annual production for 2016, production growth, year end total debt to trailing cash flow ratio for 2016, and capital expenditures for the first half and full year 2016, including the targeted amounts; the Corporation's expectation that annual production for 2016 will be within the Corporation's budget production guidance range; anticipated drilling and future development plans for the Corporation's assets; the terms of the Alberta Government's Modernized Royalty Framework, its effect on new well (including on rate of returns for Advantage's Upper, Middle and Lower Montney wells) and its expected benefits for low cost producers with higher productivity wells; anticipated commodity prices; the Corporation's hedging activities; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; lack of available capacity on pipelines; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; Advantage's ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; available pipeline capacity; that the Corporation will be able to complete the expansion and increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the year ended December 31, 2016 are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2016, Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2016 expected drilling and completion activities. Advantage has also assumed TCPL's northwest Alberta pipeline restrictions and maintenance activity level will subside in early 2016 based on the most recent information available.
Management has included the above summary of assumptions and risks related to forward-looking information provided above and in its continuous disclosure documents filed on Sedar in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. Forward-looking statements contained herein are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains certain oil and gas metrics, including cash netbacks and operating netbacks, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon.
References in this press release to production test rates, initial test production rates, and other short-term production rates are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. Additionally, such rates may also include recovered "load oil" fluids used in well completion stimulation. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for Advantage. A pressure transient analysis or well-test interpretation has not been carried out in respect of all wells. Accordingly, the Corporation cautions that the test results should be considered to be preliminary.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include funds from operations, operating netbacks and total debt to trailing cash flow ratio. Funds from operations is based on cash provided by operating activities, before expenditures on decommissioning liability and changes in non-cash working capital, reduced for finance expense excluding accretion. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
This press release and, in particular the information in respect of the Corporation's prospective cash flow debt to trailing cash flow ratio, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law]
The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, April 12, 2016 /PRNewswire/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to announce Glacier production has increased to a record 200 mmcfe/d (33,300 boe/d) as planned. Annual production for 2016 is expected to be within our previously announced Budget production guidance range of 190 to 210 mmcfe/d and is supported by a current standing well inventory of 18 completed and 14 uncompleted wells. These wells will be utilized to achieve our 2016 production target and are capable of supporting future production growth through to the second quarter of 2017. Production growth will utilize the remaining 50 mmcf/d of processing capacity that was designed into Advantage's 2015 Glacier gas plant expansion. Additionally, take-away capacity on TransCanada Pipeline's ("TCPL") sales gas pipeline in the Glacier area has recently improved as firm and interruptible transportation capacity has been increasing since March 2016.
Advantage continues to execute its 2016 capital program which is supported by the Corporation's hedge position, strong balance sheet and its industry leading low cost structure. Advantage has hedged 52% of forecast 2016 annual production at an average AECO price of Cdn $3.62/mcf and estimates that annual cash flow will meet the Corporation's planned 2016 capital program of $120 million even if AECO prices average Cdn $1.25/mcf for the remainder of the year. At an average AECO price of Cdn $2.00/mcf for 2016, Advantage estimates that its year-end total debt to trailing cash flow ratio is approximately 1.2 times.
Advantage's hedging position has been increased to 36% of forecast 2017 annual production at an average AECO price of Cdn $3.24/mcf and 52% of forecast Q1 2018 production at an average AECO price of Cdn $3.10/mcf. These hedge positions combined with our strong balance sheet provide additional financial flexibility to support the next significant expansion of Advantage's Glacier gas plant processing capacity to 350 mmcf/d planned to commence during the second half of 2017.
Advantage's Montney wells are continuing to outperform with shallower declines. Since July 2015, twelve Upper and Lower Montney wells containing an average of 18 frac stages have been placed on production and the longer producing wells are still trending approximately 1.2 mmcf/d above Advantage's Upper and Lower Montney Budget well type curve after 150 days of production. Two liquids-rich Middle Montney wells which contain an average of 19 frac stages are also demonstrating strong performance. One of these wells is producing 2 mmcf/d above our Middle Montney Budget well type curve after 230 days and the other well is meeting expectations after 84 days of production. Completed wells which contain up to 37 frac ports and with longer horizontal laterals will be brought on-production during 2016 to evaluate the impact of additional drilling and completion design changes on longer term production behaviour.
Reduced Glacier well costs reflect improved operational efficiencies and lower service costs. Well costs (drill, complete, equipping and tie-in) have continued to improve despite increased number of frac stages. For 2016, Advantage estimates that Upper Montney wells will cost $4.5 million and Lower Montney wells will cost $5.5 million based on an average of 25 fracs stages per well. Middle Montney wells are estimated to be approximately $6.0 million based on 25 frac stages. These estimates reflect well cost reductions of approximately $0.5 million per well compared to earlier wells which had 47% fewer frac stages (16 to 18 frac stages). Total completion costs on a per frac basis have decreased approximately 26% compared to realized costs in our last two drilling programs.
First Quarter 2016 results(1) continue to demonstrate Advantage's industry leading low cost structure. Average production during first quarter of 2016 increased 25% to 167 mmcfe/d compared to the first quarter of 2015. Production during the first quarter was impacted by TCPL transportation restrictions which reduced operational flexibility to offset lower production due to planned maintenance at our Glacier plant. TCPL transportation capacity has increased through March 2016 and is expected to remain higher through 2016 as compared to 2015. Advantage estimates first quarter 2016 total cash costs of approximately $0.76/mcfe including operating costs of $0.36/mcfe which is anticipated to be further reduced through 2016. Operating cost reductions are expected to result from increasing production volumes and the commissioning of an additional water disposal well in March 2016 which will lower water handling costs. Capital expenditures are estimated to be $45 million, on-track with expectations.
Advantage continues to closely monitor the natural gas price environment and can modify its growth plans as necessary to preserve financial flexibility and protect the long-term value of its Glacier Montney resource. The Corporation's hedging program, industry leading low costs, improved capital efficiencies and strengthened balance sheet have already positioned Advantage with significant downside protection and with flexibility to capitalize on improved natural gas prices which we anticipate will occur as North American natural gas supply and demand become better balanced in the near future.
Notes:
(1) All references to first quarter 2016 results are estimates and unaudited. Advantage is targeting to release actual results after-markets close on May 5, 2016.
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, Advantage's ability to grow its Glacier Montney resource play and preserve a strong balance sheet during cycles of volatility in the commodity and financial markets; Advantage's anticipated annual production for 2016, production growth for 2017, year end debt to trailing cash flow ratio for 2016, cash costs and operating costs through 2016, and cash flow and capital expenditures for 2016, including the targeted amounts and timing of achievement thereof; expected increases in production in 2016 and 2017 resulting from Advantage's Glacier development plan; the Corporation's expectation that annual cash flow for 2016 will meet the Corporation's planned capital program estimate; the Corporation's planned expansion of the Glacier gas plant processing capacity, the expected capacity, and the timing of commencement thereof; the anticipated impact of continued operational efficiencies and lower service costs on reducing well costs; the Corporation's expectations as to TCPL's transportation capacity in 2016; anticipated drilling plans; Advantage's belief that its Glacier Montney area provides the opportunity for significant long term value; Advantage's plans to monitor the natural gas price environment and modify its growth plans as necessary to preserve financial flexibility and protect the long-term value of its Glacier Montney resource; the Corporation's belief that its low costs, improved capital efficiencies and strengthened balance sheet have positioned Advantage with significant downside protection and flexibility to capitalize on improved natural gas prices; and Advantage's belief that North American natural gas supply and demand will become better balanced; and other matters. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions;Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; anticipated number of frac stages per well; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; available pipeline capacity; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; that the Corporation will be able to increase capacity at the Glacier gas plant; that Advantage's production will increase; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects.
Management has included the above summary of assumptions and risks related to forward-looking information provided above in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Certain type curves referred to in this press release represent estimates of the production decline and ultimate volumes expected to be recovered from wells over the life of the well. 7.2 Bcfe Upper and Lower Montney Budget type curves and 4.5 Bcfe Middle Montney Budget type curves are management generated type curves based on a combination of historical performance of older wells and management's expectation of what might be achieved from future wells. The type curves represent what management thinks an average well will achieve. Individual wells may be higher or lower but over a larger number of wells management expects the average to come out to the type curve. Over time type curves can and will change based on achieving more production history on older wells or more recent completion information on newer wells.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"), including total debt to trailing cash flow ratio. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit, divided by funds from operations for the prior twelve month period. Management believes that such financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures.
This press release and, in particular the information in respect of the Corporation's prospective annual cash flow for 2016, may contain future oriented financial information ("FOFI") within the meaning of applicable securities laws. The FOFI has been prepared by management to provide an outlook of the Corporation's activities and results and may not be appropriate for other purposes. The FOFI has been prepared based on a number of assumptions including the assumptions discussed above. The actual results of operations of the Corporation and the resulting financial results may vary from the amounts set forth herein, and such variations may be material. The Corporation and management believe that the FOFI has been prepared on a reasonable basis, reflecting management's best estimates and judgments. FOFI contained in this press release was made as of the date of this press release and the Corporation disclaims any intention or obligations to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law.
The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
kpa |
kilopascal |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
(TSX: AAV, NYSE: AAV)
CALGARY, March 3, 2016 /PRNewswire/ - During 2015, Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") achieved industry leading operating efficiencies as the Corporation continued to advance its Glacier Montney development. Advantage reduced 2015 total cash costs by 8% to $0.82/mcfe and to $0.77/mcfe in the fourth quarter of 2015, added proven plus probable ("2P") reserves at a finding and development ("F&D") cost of $0.77/mcfe ($4.65/boe) (1) and expanded its 100% owned Glacier gas plant processing capacity to 250 mmcf/d to accommodate growth through 2017.
These achievements reaffirm our belief in the long term value of the Corporation's Glacier Montney asset and with an estimated pro-forma 2016 year-end total debt to trailing cash flow of approximately 1.0 times based on our annual budget(2), Advantage has announced plans to expand its Glacier gas plant process capacity beginning in the second half of 2017 to 350 mmcf/d to accommodate future growth.
We sincerely thank Advantage's Board of Directors, our shareholders and especially the dedication and extra-efforts of our staff who have contributed to the Corporation's ongoing success and achievements.
Notes: | |
(1) |
Please refer to Advantage's Year-end 2015 Reserves press release dated February 16, 2016 for additional details. F&D costs are calculated by dividing total capital by reserve additions during the applicable period. Total capital includes both capital expenditures incurred and changes in future development capital required to bring proved undeveloped reserves and probable reserves to production during the applicable period. Reserve additions is calculated as the change in reserves from the beginning to the end of the applicable period excluding production. |
(2) |
The pro-forma budgeted 2016 year-end total debt to trailing cash flow is based on AECO Cdn $2.50/mcf and Advantage's current hedge positions and includes estimated net proceeds of approximately $95 million (includes the estimated net proceeds from the over-allotment option) resulting from the Corporation's bought deal equity financing announced on February 18, 2016 (the "Bought Deal"). |
2015 Operating and Financial Highlights
Production increased 16% to 155.3 mmcfe/d (25,886 boe/d) for the fourth quarter of 2015 and 7% to 141 mmcfe/d for 2015 as compared to the similar periods in 2014. Production growth was achieved despite a total of 107 days of TransCanada Pipelines Ltd. ("TCPL") firm service sales pipeline restrictions and outages realized from April to December 2015 and additional production interruptions required during the construction and expansion of Advantage's Glacier gas plant.
Funds from operations for full year 2015 was $123.6 million or $0.72 per share and $31.7 million or $0.19 per share for the fourth quarter. Hedging gains of $8.8 million and $32.7 million during the three months and year ended December 31, 2015, respectively, partially offset the decrease in Canadian natural gas prices. Advantage's cash netback for 2015 was $2.40/mcfe ($14.43/boe) which represents 75% of the realized sales price, including hedging.
Total debt as of December 31, 2015 was $294 million including working capital deficit as compared to our $450 borrowing base Credit Facility. Total debt including working capital deficit at December 31, 2015 reduced for the estimated net proceeds of the Bought Deal (including the over-allotment option) would be $199 million. Advantage's Credit Facility borrowing base was reconfirmed at $450 million during its normal semi-annual review process in October 2015. This results in a year-end 2015 undrawn bank line of $163 million that would increase to $258 million after application of the estimated Bought Deal net proceeds, which provides continued financial flexibility to support future development.
Total cash costs decreased 8% to $0.82/mcfe in 2015 with the fourth quarter of 2015 decreased by 7% to $0.77/mcfe as compared to the same periods of 2014. Total cash costs of $0.77/mcfe in the fourth quarter of 2015 include operating expense ($0.35/mcfe), royalties ($0.10/mcfe), general and administrative expense ($0.11/mcfe), and finance expense ($0.21/mcfe).
Strong natural gas hedge positions averaging 52% of forecast net production for 2016 at an average AECO floor price of Cdn $3.62/mcf provides near term downside gas price protection. For 2017 and the first quarter of 2018, Advantage has hedged an average 31% and 37% of its forecast net production at an average AECO floor price of Cdn $3.24/mcf and Cdn $3.12/mcf, respectively.
2015 TCPL Sales Gas Pipeline Restrictions Subsiding in 2016
Advantage experienced a total 107 days of TCPL firm service sales pipeline restrictions and outages from April to December 2015. Additionally, no interruptible ("IT") service was available in the Glacier area after April 2015 resulting in limited flexibility to offset normal maintenance activities or production outages required during our construction work at the Glacier gas plant. TCPL pipeline capacity in northwest Alberta is currently increasing after additional firm service restrictions occurred in January and February 2016 in the Glacier area. Advantage anticipates the availability of IT service will increase during the remainder of the first quarter of 2016 which should allow throughput capacity testing of the Corporation's expanded Glacier gas plant.
Looking Forward
Advantage's achievements in 2015 and its ongoing focus on operational and capital efficiencies continue to strengthen the foundation of our Glacier Montney development program to generate profitable growth in this low commodity price environment.
For 2016, Advantage's current standing well inventory of 37 total standing wells (23 completed and 14 uncompleted) are expected to provide sufficient productive capacity to attain the Corporation's previously announced average annual production guidance for the year ended December 31, 2016 of 190 to 210 mmcfe/d.
The Glacier gas plant expansion completed in 2015 increased processing capacity to 250 mmcf/d and provided 70 mmcf/d of additional capacity to meet future growth in 2016 and 2017. Advantage's future facility growth plans include another significant expansion of the Glacier gas plant beginning in the second half of 2017 to increase processing capacity by 100 mmcf/d to a total of 350 mmcf/d to support future growth. Additionally, Advantage's 100% ownership of the Glacier gas plant provides flexibility to process varying amounts of dry and liquids rich gas to optimize investment returns and cash netbacks.
Consolidated Financial Statements and MD&A
The Corporation's audited consolidated financial statements for the fiscal year ended December 31, 2015 together with the notes thereto, and Management's Discussion and Analysis for the year ended December 31, 2015 have been filed on SEDAR and with the SEC and are available on the Corporation's website at http://www.advantageog.com/investors/financial-reports/2015. The Corporation's audited consolidated financial statements for the fiscal year ended December 31, 2014 are also available on the Corporation's website via the same webpage. Upon request, Advantage will provide a hard copy of any financial reports free of charge.
Appendix - Fourth Quarter and Full Year 2015 Operating & Financial Summary
Three months ended |
Year ended | ||||||||
Financial and Operating Highlights (1) |
December 31 |
December 31 | |||||||
2015 |
2014 |
2015 |
2014 | ||||||
Financial ($000, except as otherwise indicated) |
|||||||||
Sales including realized hedging |
$ |
42,654 |
$ |
46,409 |
$ |
165,054 |
$ |
203,103 | |
Funds from operations |
$ |
31,656 |
$ |
39,182 |
$ |
123,630 |
$ |
164,010 | |
per share(2) |
$ |
0.19 |
$ |
0.23 |
$ |
0.72 |
$ |
0.97 | |
Total capital expenditures |
$ |
27,604 |
$ |
87,086 |
$ |
164,983 |
$ |
236,701 | |
Working capital deficit(3) |
$ |
7,196 |
$ |
57,264 |
$ |
7,196 |
$ |
57,264 | |
Bank indebtedness |
$ |
$286,519 |
$ |
109,970 |
$ |
286,519 |
$ |
109,970 | |
Convertible debentures (face value) |
$ |
- |
$ |
86,250 |
$ |
- |
$ |
86,250 | |
Basic weighted average shares (000) |
170,742 |
170,068 |
170,608 |
169,482 | |||||
Operating |
|||||||||
Daily Production |
|||||||||
Natural gas (mcf/d) |
154,241 |
133,433 |
139,927 |
130,627 | |||||
Liquids (bbls/d) |
179 |
113 |
154 |
159 | |||||
Total mcfe/d(4) |
155,315 |
134,111 |
140,851 |
131,581 | |||||
Total boe/d(4) |
25,886 |
22,352 |
23,475 |
21,930 | |||||
Average prices (including hedging) |
|||||||||
Natural gas ($/mcf) |
$ |
2.96 |
$ |
3.72 |
$ |
3.18 |
$ |
4.15 | |
Liquids ($/bbl) |
$ |
43.24 |
$ |
71.35 |
$ |
44.60 |
$ |
89.84 | |
Cash netbacks ($/mcfe)(4) |
|||||||||
Natural gas and liquids sales |
$ |
2.37 |
$ |
3.82 |
$ |
2.57 |
$ |
4.49 | |
Realized gains (losses) on derivatives |
0.61 |
(0.06) |
0.64 |
(0.26) | |||||
Royalties |
(0.10) |
(0.18) |
(0.11) |
(0.21) | |||||
Operating expense |
(0.35) |
(0.34) |
(0.36) |
(0.32) | |||||
Operating netback |
2.53 |
3.24 |
2.74 |
3.70 | |||||
General and administrative |
(0.11) |
(0.11) |
(0.14) |
(0.15) | |||||
Finance expense |
(0.21) |
(0.20) |
(0.21) |
(0.21) | |||||
Other income (expense) |
(0.01) |
0.25 |
0.01 |
0.09 | |||||
Cash netbacks |
$ |
2.20 |
$ |
3.18 |
$ |
2.40 |
$ |
3.43 | |
(1) |
Financial and operating highlights for continuing operations of Advantage. | ||||||||
(2) |
Based on basic weighted average shares outstanding. | ||||||||
(3) |
Working capital deficit includes trade and other receivables, prepaid expenses and deposits, and trade and other accrued liabilities. | ||||||||
(4) |
A boe and mcfe conversion ratio has been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to | ||||||||
one barrel of liquids. |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "guidance", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "believe", "would" and similar expressions and include statements relating to, among other things, Advantage's belief in the long term value of the Corporation's Glacier Montney asset; estimate pro-forma 2016 year-end total debt to trailing cash flow; Advantage's plans to expand its Glacier gas plant processing capacity, including the expected timing and anticipated processing capacity as a result thereof; the Corporation's anticipated debt levels as a result of the Bought Deal; Advantage's expectation with respect to the availability of IT service during the remainder of the first quarter of 2016 and the anticipated effect on throughput capacity testing of the expanded Glacier gas plant; drilling and future development plans for the Corporation's assets; anticipated operational results for the year ended December 31, 2016, including, but not limited to, anticipated production levels and drilling plans; Advantage's belief that its current standing well inventory will provide sufficient productive capacity to attain anticipated production levels; anticipated commodity prices; the Corporation's hedging activities; statements related to the Bought Deal, including the exercise of the over-allotment option; and other matters.
Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: risks related to the Bought Deal; changes in general economic, market and business conditions; industry conditions; impact of significant declines in market prices for oil and natural gas; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.Sedar.com and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: the estimated net proceeds from the Bought Deal; conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects. Production estimates contained herein for the year ended December 31, 2016 are expressed as anticipated average production over the calendar year. In determining anticipated production for the year ended December 31, 2016, Advantage considered historical drilling, completion and production results for prior years and took into account the estimated impact on production of the Corporation's 2016 expected drilling and completion activities. Advantage has also assumed TCPL's northwest Alberta pipeline restrictions and maintenance activity level will subside in early 2016 based on the most recent information available.
Management has included the above summary of assumptions and risks related to forward-looking information provided above its continuous disclosure as filed on Sedar in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive.
These forward-looking statements are made as of the date of this press release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
This press release contains certain oil and gas metrics, including F&D costs, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods and therefore such metrics should not be unduly relied upon.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). These financial measures include operating netbacks and total debt to trailing cash flow ratio. Cash netbacks are dependent on the determination of funds from operations and include the primary cash sales and expenses on a per mcfe basis that comprise funds from operations. Total debt to trailing cash flow ratio is calculated as indebtedness under the Corporation's credit facilities plus working capital deficit divided by funds from operations for the prior twelve month period. Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
The following abbreviations used in this press release have the meanings set forth below:
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas |
boe/d |
barrels of oil equivalent per day |
GJ |
gigajoule |
kpa |
kilopascal |
mcf |
thousand cubic feet |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs |
mmcf |
million cubic feet |
mmcf/d |
million cubic feet per day |
mmcfe |
million cubic feet equivalent |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
Glacier Montney Development Drives Strong Efficiencies with
$0.77 per Mcfe Finding & Development Cost,
390% Reserve Replacement and 3.3x Recycle Ratio
(TSX: AAV, NYSE: AAV)
CALGARY, Feb. 16, 2016 /CNW/ - Advantage Oil & Gas Ltd. ("Advantage" or the "Corporation") is pleased to report that the Corporation's continued focus on improving well performance, capital efficiencies and lowering cash costs have resulted in highly efficient 2015 reserve additions from its Glacier Montney development program. Positive technical revisions resulting from improved production performance contributed significantly to reserve additions and reinforces the quality of our Montney reservoir at Glacier. As we continue to advance our growth plans toward our annual average production target of 200 mmcfe/d in 2016 and 235 mmcfe/d in 2017, we believe this lower commodity price environment will persist and Advantage's focus on enhancing financial strength and operational excellence will be critical to capitalizing on lower costs and opportunities to grow long term value.
Advantage's 2015 Proved plus Probable ("2P") Finding and Development cost of $0.77/mcfe including the change in future development capital ("FDC") confirms eight consecutive years of highly efficient Montney reserve additions. The Corporation's three year average 2P F&D cost is $1.10/mcfe ($6.63/boe) including the change in FDC. The 2015 Proved ("1P") F&D cost is $0.87/mcfe ($5.22/boe) and the Proved Developed Producing ("PDP") F&D cost is $2.21/mcfe ($13.29/boe) including the change in FDC. These reserve addition costs were achieved with 45% ($75 million) invested in facilities expansions out of a total capital expenditure amount of $165 million in 2015. This included $65 million to increase processing capacity to 250 mmcf/d at Advantage's 100% owned Glacier gas plant to accommodate growth through 2017 and $10 million for sales pipelines.
The Corporation's 1P gross working interest reserves increased 11% to 1.28 Tcfe (213.2 million boe) and 2P gross working interest reserves increased 8% to 1.95 Tcfe (325.3 million boe) replacing 390% of 2015 production. Technical revisions resulting from improved well performance accounted for 27% and 53% of the 2P and 1P reserves additions, respectively. The 2015 2P reserves include 297 undeveloped Glacier Montney locations of which only 18 new locations were added in 2015. Management estimates approximately 1,000 total Montney locations remains undrilled at Glacier. (Reserve replacement is calculated by dividing 2P reserves net volume additions by the current annual production expressed as a percentage).
PDP reserves increased 8% to 302 Bcfe. Advantage's improved well performance resulted in significantly less wells placed on-production than anticipated to support an increase in production from 130 mmcfe/d to 180 mmcfe/d in 2015. As a result, only 13 new wells in 2015 were assigned PDP reserves with an additional 10 wells remaining in the proved non-producing category and 14 wells rig released in 2015 which remained standing. These wells will be converted to PDP as they are placed on-production through 2016.
Advantage's 2015 2P recycle ratio of 3.3x and three year average 2P recycle ratio of 2.8x highlights the ongoing profitability of its Montney development program and the Corporation's success in achieving improved operational and cost efficiencies that have substantially offset the significant decline in natural gas prices since 2008. The Corporation's 2015 1P recycle ratio is 2.9x and the PDP recycle ratio is 1.1x. The recycle ratio is based on Advantage's fourth quarter 2015 operating netback of $2.53/mmcfe ($15.18/boe).
2P Reserves per share increased 8% reflecting Advantage's ongoing success and growth. Since 2008, Advantage's Glacier Montney development program resulted in an average annual 2P reserves growth of 75% per share (reserves per share calculated as 2P reserves divided by the number of shares issued and outstanding at year-end which was 170.8 million shares at December 31, 2015).
Continuing Glacier outperformance lowers capital expenditure requirements by $215 million from initial estimates of $700 million to $485 million to execute Advantage's 2015 through 2017 development plan. The cumulative efficiencies achieved to date have allowed the Corporation to maintain its growth plans and preserve a strong balance sheet despite lower natural gas prices. This is reflected in our 2016 Budget which is targeted to deliver 39% production per share growth with an estimated year-end total debt to 2016 annual funds from operations of 1.6x at an average AECO natural gas price of Cdn $2.50/mcf (refer to Advantage's "2016 Guidance and Development Plan Update" press release dated December 16, 2015).
Notable 2015 Reserve Changes and Analysis
Sproule Associates Ltd. ("Sproule") was engaged as an independent qualified reserve evaluator to evaluate Advantage's year-end reserves as of December 31, 2015 ("Sproule 2015 reserve report") in accordance with National Instrument 51-101 ("NI 51-101") and the Canadian Oil and Gas Evaluation Handbook ("COGE Handbook"). Reserves are stated on a gross (before royalties) working interest basis unless otherwise indicated. Additional details are provided in the attached tables beginning on page 5 of this release and additional reserve information as required under NI 51-101 will be included in our Annual Information Form which will be filed on SEDAR on or before March 30, 2016.
All references to year end 2015 financial and operating data in this release are estimates and are unaudited. Advantage is targeting to report on its audited 2015 financial and operating results after markets on March 3, 2016.
Reserve |
Conventional Tcf |
NGLs Million bbls |
Total Gas Tcfe |
% Change from | |||
PDP |
0.29 |
2.49 |
0.30 |
8% | |||
1P |
1.21 |
12.10 |
1.28 |
11% | |||
2P |
1.83 |
20.12 |
1.95 |
8% |
Q4 2015 ($/mcfe) | ||||||||||
Revenue (1) |
$2.98 | |||||||||
Royalties |
$0.10 | |||||||||
Operating cost |
$0.35 | |||||||||
Operating netback |
$2.53 | |||||||||
2P Recycle Ratio for 2015 (2) |
3.3x | |||||||||
2P Recycle Ratio average for last 3 years (2) |
2.8x |
(1) |
Q4 2015 revenue includes adjustments for transportation costs, heat value and hedging gains of $0.61/mcfe | |||
(2) |
The recycle ratio for 2015 represents the Q4 operating netback per mcfe divided by the 2P F&D cost per mcfe including the change in FDC. The 3-year recycle ratio utilizes the average operating netback per mcfe over the last 3 years divided by the 3-year average 2P F&D cost per mcfe including the change in FDC. |
Sproule # of Gross Horizontal Wells Booked |
Sproule Average EUR/well (bcf raw /well) | ||||||||
Developed |
Undeveloped |
Undeveloped | |||||||
Upper |
100 |
148 |
5.5 | ||||||
Middle |
19 |
66 |
4.6 | ||||||
Lower |
34 |
83 |
5.9 | ||||||
Total |
153 |
297 |
Operational Update
During the fourth quarter of 2015 production increased 16% over the same period in 2014 to 155 mmcfe/d. Advantage experienced 40 days of TransCanada Pipelines Limited ("TCPL") firm service restrictions with no interruptible service ("IT") available in the Glacier area. The amount of TCPL restrictions in the fourth quarter of 2015 were slightly more than anticipated.
TCPL pipeline capacity in northwest Alberta is currently increasing after continued firm service restrictions occurred in January and February 2016 in the Glacier area. Advantage anticipates the availability of IT service will increase during the remainder of the first quarter of 2016 which should allow throughput capacity testing of our expanded Glacier gas plant.
Advantage's Upper, Middle and Lower Montney wells are continuing to demonstrate strong production performance and less wells have been required to maintain production than expected. Advantage's current standing well inventory consisted of 37 total standing wells of which 23 are completed and 14 remain uncompleted providing more than sufficient productive capacity to attain our 2016 annual production target of 200 mmcfe/d.
Key operational results during the fourth quarter of 2015 and for calendar 2015 are indicated below:
Q4 2015 |
2015 | ||||||
Production (mmcfe/d) |
155 |
141 | |||||
Royalties % |
4.1% |
4.4% | |||||
Operating Cost ($/mcfe) |
$0.35 |
$0.36 | |||||
Total Cash Cost ($/mcfe) (1) |
$0.77 |
$0.82 | |||||
Capital Expenditures ($ millions) |
$28 |
$165 | |||||
Total Debt including working capital ($ millions) |
$294 |
$294 | |||||
Funds from Operations ($ millions) |
$32 |
$124 |
(1) |
Total cash cost includes royalties, operating cost, general and administrative expense, and finance expense. |
Hedging Update
Advantage increased its hedging positions for 2017 and Q1 2018. A summary of the hedge positions are included below:
% of net Forecasted Production |
Average AECO Cdn $/Mcf | ||||||
2016 |
52% |
$3.62/mcf | |||||
2017 |
22% |
$3.31/mcf | |||||
Q1 2018 |
26% |
$3.17/mcf |
Looking Forward
The 2015 reserve report demonstrates another year of highly efficient reserve additions at Glacier reaffirming the exceptional quality of our Montney asset and reflecting the continuing operational achievements that have been realized. Advantage remains highly focused on maintaining operational and financial flexibility in conjunction with growth plans that generate profitability during lower commodity price cycles while preserving the significant future upside value in our assets. We look forward to reporting on our progress through 2016.
RESERVE SUMMARY TABLES
Company Gross (before royalties) Working Interest Reserves
Summary as at December 31, 2015
Light & Medium (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional (mmcf) |
Total Oil (mboe) | |
Proved |
||||
Developing Producing |
9 |
2,496 |
287,183 |
50,369 |
Developed Non-producing |
- |
913 |
43,164 |
8,107 |
Undeveloped |
- |
8,689 |
876,137 |
154,712 |
Total Proved |
9 |
12,097 |
1,206,484 |
213,187 |
Probable |
3 |
8,024 |
624,800 |
112,160 |
Total Proved + Probable |
12 |
20,121 |
1,831,284 |
325,347 |
(1) |
Tables may not add due to rounding. |
Company Net Present Value of Future Net Revenue using Sproule price and cost forecasts (1)(2)(3)
($000)
Before Income Taxes Discounted at | |||||||
0% |
10% |
15% | |||||
Proved |
|||||||
Developed Producing |
742,984 |
508,466 |
433,824 | ||||
Developed Non-producing |
154,300 |
93,084 |
77,262 | ||||
Undeveloped |
2,275,829 |
613,326 |
336,331 | ||||
Total Proved |
3,173,112 |
1,214,876 |
847,417 | ||||
Probable |
2,476,139 |
820,548 |
558,203 | ||||
Total Proved + Probable |
5,649,252 |
2,035,424 |
1,405,620 | ||||
(1) |
Advantage's light, medium and heavy oil, conventional natural gas and natural gas liquid reserves were evaluated using Sproule's product price forecast effective December 31, 2015 prior to the provision for income taxes, interests, debt services charges and general and administrative expenses. It should not be assumed that the discounted future net revenue estimated by Sproule represents the fair market value of the reserves. |
(2) |
Assumes that development of Glacier will occur, without regard to the likely availability to the Corporation of funding required for that development. |
(3) |
Future Net Revenue incorporates Managements' estimates of required abandonment and reclamation costs, including expected timing such costs will be incurred, associated with all wells, facilities and infrastructure. No abandonment and reclamation costs have been excluded. |
(4) |
Tables may not add due to rounding. |
Sproule Price Forecasts
The present value of future net revenue at December 31, 2015 was based upon natural gas and natural gas liquids pricing assumptions prepared by Sproule effective December 31, 2015. These forecasts are adjusted for reserve quality, transportation charges and the provision of any applicable sales contracts. The price assumptions used over the next seven years are summarized in the table below:
Year |
Alberta AECO-C Natural Gas ($Cdn/mmbtu) |
Henry Hub Natural Gas ($US/mmbtu) |
Edmonton Propane ($Cdn/bbl) |
Edmonton Butane ($Cdn/bbl) |
Edmonton Pentanes Plus ($Cdn/bbl) |
Exchange Rate ($US/$Cdn) |
2016 |
2.25 |
2.25 |
9.09 |
39.09 |
59.10 |
0.75 |
2017 |
2.95 |
3.00 |
13.64 |
51.43 |
73.88 |
0.80 |
2018 |
3.42 |
3.50 |
25.84 |
58.46 |
83.98 |
0.83 |
2019 |
3.91 |
4.00 |
35.35 |
66.64 |
95.73 |
0.85 |
2020 |
4.20 |
4.25 |
42.30 |
68.35 |
98.19 |
0.85 |
2021 |
4.28 |
4.31 |
42.94 |
69.38 |
99.66 |
0.85 |
2022 |
4.35 |
4.38 |
43.58 |
70.42 |
101.16 |
0.85 |
Company Gross (before royalties) Working Interest Reserves Reconciliation (1):
Proved |
Light & (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional Gas (mmcf) |
Total Oil Equivalent (mboe) |
Opening balance Dec. 31, 2014 |
4.9 |
8,442 |
1,101,700 |
192,063 |
Extensions |
- |
160 |
3,234 |
699 |
Infill Drilling |
- |
1,901 |
83,102 |
15,751 |
Improved recovery |
- |
- |
- |
- |
Technical revisions |
5.2 |
1,753 |
83,996 |
15,758 |
Discoveries |
- |
- |
- |
- |
Acquisitions |
- |
- |
- |
- |
Dispositions |
- |
- |
- |
- |
Economic factors |
(0.1) |
(101) |
(14,482) |
(2,515) |
Production |
(0.6) |
(57) |
(51,066) |
(8,569) |
Closing balance at Dec. 31, 2015 |
9.4 |
12,097 |
1,206,484 |
213,187 |
Proved + Probable |
Light & (mbbl) |
Natural Gas Liquids (mbbl) |
Conventional Gas (mmcf) |
Total Oil Equivalent (mboe) |
Opening balance Dec. 31, 2014 |
6.8 |
15,682 |
1,709,216 |
300,558 |
Extensions |
- |
478 |
13,795 |
2,778 |
Infill Drilling |
- |
2,835 |
133,044 |
25,009 |
Improved recovery |
- |
- |
- |
- |
Technical revisions |
6.1 |
1,314 |
45,963 |
8,980 |
Discoveries |
- |
- |
- |
- |
Acquisitions |
- |
- |
- |
- |
Dispositions |
- |
- |
- |
- |
Economic factors |
(0.1) |
(130) |
(19,668) |
(3,408) |
Production |
(0.6) |
(57) |
(51,066) |
(8,569) |
Closing balance at Dec. 31, 2015 |
12.2 |
20,121 |
1,831,284 |
325,347 |
(1) |
Technical revisions accounted for 53% of the total proved additions and 27% of the total proved + probable additions. Percentage of each category calculated by dividing the technical revisions in the category by the total reserve additions in the same category before production. |
(2) |
Tables may not add due to rounding. |
Company Finding & Development Costs ("F&D")
Company 2015 F&D Costs – Gross (before royalties) Working Interest Reserves including Future Development Capital - NI 51-101 (1)(2)(3)(4)
Proved |
Proved + Probable | |||
Capital expenditures ($000) |
164,983 |
164,983 | ||
Net change in Future Development Capital ($000) |
(9,895) |
(9,948) | ||
Total capital ($000) |
155,088 |
155,035 | ||
Total mboe, end of year |
213,187 |
325,347 | ||
Total mboe, beginning of year |
192,063 |
300,558 | ||
Production, mboe |
8,569 |
8,569 | ||
Reserve additions, mboe |
29,693 |
33,358 | ||
2015 F&D costs ($/boe) |
$5.22 |
$4.65 | ||
2014 F&D costs ($/boe) |
$9.76 |
$6.17 | ||
Three-year average F&D costs ($/boe) |
$8.37 |
$6.63 |
(1) |
F&D costs are calculated by dividing total capital by reserve additions during the applicable period. Total capital includes both capital expenditures incurred and changes in FDC required to bring the proved undeveloped and probable reserves to production during the applicable period. Reserve additions is calculated as the change in reserves from the beginning to the ending of the applicable period excluding production. |
(2) |
The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated FDC generally will not reflect total finding and development costs related to reserves additions for that year. Changes in forecast FDC occur annually as a result of development activities, acquisition and disposition activities and capital cost estimates that reflect Sproule's best estimate of what it will cost to bring the proved undeveloped and probable reserves on production. |
(3) |
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value. |
(4) |
The change in FDC results primarily from on average $433,000 lower capital costs per booked location offset by higher capital inflation costs for three years (4%/year), additional booked locations and additional facility capital in 2018. |
Advisory
The information in this press release contains certain forward-looking statements, including within the meaning of the United States Private Securities Litigation Reform Act of 1995. These statements relate to future events or our future intentions or performance. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "demonstrate", "expect", "may", "can", "will", "project", "predict", "potential", "target", "intend", "could", "might", "should", "guidance", "believe", "would" and similar expressions and include statements relating to, among other things, Advantage's capital budget for 2016, including anticipated production growth, debt-to-cash flow ratio and anticipated capital expenditures for the 2015 through 2017 development plan; Advantage's anticipated future production from the Glacier Montney resource play and the expected timing thereof; the expected timing of release of Advantage's 2015 financial and operational results; estimated production from Advantage's wells and the timing of achievement thereof; estimated number of drilling locations and Advantage's belief that it's well inventory provides sufficient productive capacity to attain its 2016 annual production target; the expected capabilities of Advantage's gas plant, including processing capability; Advantage's estimated fourth quarter and full year 2015 financial and operating results including production, operating costs, total cash costs, capital expenditures, total debt including working capital, and funds from operations; anticipated increase to the availability of interruptible ("IT") service and the expected timing thereof; terms of the Corporation's hedging contracts; and Advantage's focus on maintaining operational and financial flexibility in conjunction with growth plans that generate profitability during lower commodity price cycles. In addition, statements relating to "reserves" are by their nature forward-looking statements, as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. The recovery and reserve estimates of Advantage's reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Advantage's actual decisions, activities, results, performance or achievement could differ materially from those expressed in, or implied by, such forward-looking statements and accordingly, no assurances can be given that any of the events anticipated by the forward-looking statements will transpire or occur or, if any of them do, what benefits that Advantage will derive from them.
These statements involve substantial known and unknown risks and uncertainties, certain of which are beyond Advantage's control, including, but not limited to: changes in general economic, market and business conditions; industry conditions; actions by governmental or regulatory authorities including increasing taxes and changes in investment or other regulations; changes in tax laws, royalty regimes and incentive programs relating to the oil and gas industry; the effect of acquisitions; Advantage's success at acquisition, exploitation and development of reserves; unexpected drilling results; changes in commodity prices, currency exchange rates, capital expenditures, reserves or reserves estimates and debt service requirements; the occurrence of unexpected events involved in the exploration for, and the operation and development of, oil and gas properties, including hazards such as fire, explosion, blowouts, cratering, and spills, each of which could result in substantial damage to wells, production facilities, other property and the environment or in personal injury; changes or fluctuations in production levels; delays in anticipated timing of drilling and completion of wells; delays in completion of the expansion of the Glacier gas plant; individual well productivity; competition from other producers; the lack of availability of qualified personnel or management; credit risk; changes in laws and regulations including the adoption of new environmental laws and regulations and changes in how they are interpreted and enforced; our ability to comply with current and future environmental or other laws; stock market volatility and market valuations; liabilities inherent in oil and natural gas operations; uncertainties associated with estimating oil and natural gas reserves; competition for, among other things, capital, acquisitions of reserves, undeveloped lands and skilled personnel; incorrect assessments of the value of acquisitions; geological, technical, drilling and processing problems and other difficulties in producing petroleum reserves; ability to obtain required approvals of regulatory authorities; and ability to access sufficient capital from internal and external sources. Many of these risks and uncertainties and additional risk factors are described in the Corporation's Annual Information Form which is available at www.sedar.com ("SEDAR") and www.advantageog.com. Readers are also referred to risk factors described in other documents Advantage files with Canadian securities authorities.
With respect to forward-looking statements contained in this press release, Advantage has made assumptions regarding, but not limited to: conditions in general economic and financial markets; effects of regulation by governmental agencies; current and future commodity prices and royalty regimes; future exchange rates; royalty rates; future operating costs; availability of skilled labor; availability of drilling and related equipment; timing and amount of capital expenditures; the impact of increasing competition; the price of crude oil and natural gas; that the Corporation will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that the Corporation's conduct and results of operations will be consistent with its expectations; that the Corporation will have the ability to develop the Corporation's properties in the manner currently contemplated; current or, where applicable, proposed assumed industry conditions, laws and regulations will continue in effect or as anticipated; and the estimates of the Corporation's production and reserves volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects.
Management has included the above summary of assumptions and risks related to forward-looking information above and in its continuous disclosure filings on SEDAR in order to provide shareholders with a more complete perspective on Advantage's future operations and such information may not be appropriate for other purposes. Advantage's actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits that Advantage will derive there from. Readers are cautioned that the foregoing lists of factors are not exhaustive. These forward-looking statements are made as of the date of this news release and Advantage disclaims any intent or obligation to update publicly any forward-looking statements, whether as a result of new information, future events or results or otherwise, other than as required by applicable securities laws.
Barrels of oil equivalent (boe) and thousand cubic feet of natural gas equivalent (mcfe) may be misleading, particularly if used in isolation. Boe and mcfe conversion ratios have been calculated using a conversion rate of six thousand cubic feet of natural gas equivalent to one barrel of oil. A boe and mcfe conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.
This press release contains a number of oil and gas metrics, including F&D, recycle ratio, reserve replacement and reserve life index, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies and should not be used to make comparisons. Such metrics have been included herein to provide readers with additional measures to evaluate the Corporation's performance; however, such measures are not reliable indicators of the future performance of the Corporation and future performance may not compare to the performance in previous periods.
The recovery and reserve estimates of reserves provided in this news release are estimates only, and there is no guarantee that the estimated reserves will be recovered. Actual reserves may eventually prove to be greater than, or less than, the estimates provided herein.
This press release discloses drilling locations in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations are derived from the Corporation's most recent independent reserves evaluation as prepared by Sproule as of December 31, 2015 and account for drilling locations that have associated proved and/or probable reserves, as applicable. Unbooked locations are internal estimates based on the Corporation's prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Unbooked locations have been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, engineering, production and reserves information. There is no certainty that the Corporation will drill all unbooked drilling locations and if drilled there is no certainty that such locations will result in additional oil and gas reserves, resources or production. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, other unbooked drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production.
The Corporation discloses several financial measures that do not have any standardized meaning prescribed under International Financial Reporting Standards ("IFRS"). Management believes that these financial measures are useful supplemental information to analyze operating performance and provide an indication of the results generated by the Corporation's principal business activities. Investors should be cautioned that these measures should not be construed as an alternative to net income or other measures of financial performance as determined in accordance with IFRS. Advantage's method of calculating these measures may differ from other companies, and accordingly, they may not be comparable to similar measures used by other companies. Please see the Corporation's most recent Management's Discussion and Analysis, which is available at www.sedar.com and www.advantageog.com for additional information about these financial measures, including a reconciliation of funds from operations to cash provided by operating activities.
Certain financial and operating results included in this news release including production, operating costs, total cash costs, capital expenditures, total debt including working capital, and funds from operations are based on unaudited estimated results. These estimated results are subject to change upon completion of the Corporation's audited financial statements for the year ended December 31, 2015, and changes could be material. Advantage anticipates filing its audited financial statements and related management's discussion and analysis for the year ended December 31, 2015 on SEDAR on or before March 30, 2016.
The following abbreviations used in this press release have the meanings set forth below:
bbls |
Barrels | |
boe |
barrels of oil equivalent of natural gas, on the basis of one barrel of oil or NGLs for six thousand cubic feet of natural gas | |
mcf |
thousand cubic feet | |
mmcf |
million cubic feet | |
mmcf/d |
million cubic feet per day | |
mcfe |
thousand cubic feet equivalent on the basis of six thousand cubic feet of natural gas for one barrel of oil or NGLs | |
mmcfe |
million cubic feet equivalent | |
mmcfe/d |
million cubic feet equivalent per day |
SOURCE Advantage Oil & Gas Ltd.
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