Events Calendar
Overview: The Ordovician Utica shale is an international shale play, stretching from Quebec, Canada, down in the U.S. portion of the great Appalachian Basin. The Utica offers strong attractions: excellent rock properties, low acreage costs, and proximity to premium gas markets. This emerging play is on the cusp of exploration, with operators beginning to probe its potential in earnest. Here, in the webinar “Unlocking the Utica: The Next Big Northeast Shale Play?” you will hear the latest insights on this fascinating reservoir from two industry experts. The 55-minute webinar will include a live Q&A moderated by Peggy Williams, Director of Unconventional Resources, Hart Energy.
Argentina’s Neuquén Basin holds a wealth of tight gas and shale reservoirs, and companies are launching drilling programs to assess these resources. Explorers are targeting the thick and rich Vaca Muerta and Los Molles shales, two well-known, world-class source rocks that are receiving new attention. A discovery by Repsol YPF in the oil-prone portion of the Vaca Muerta could hold 150 million barrels of recoverable oil, and the company has already kicked off a major development project. Operators are also testing unconventional gas prospects in both shales, and in tight-gas sands. In addition to its attractive geology, the Neuquén Basin has other attributes that favor unconventional development. It has a long history of oil and gas operations, is home to an established, thriving service sector, and has excellent access to markets.
‘Night Dragon’ and ‘Stuxnet’ attacks have unleashed a flurry of media coverage. In the face of these advanced and persistent threats to your real-time systems and intellectual property do you need to think and act differently than you have in the past?
As cyber security threats escalate and the level of process automation increases, the oil and gas industry is taking lessons from downstream plants and the utility industry. Nation state attackers are the biggest threat to the industry, but many unknown threats also exist worldwide. If your corporate reputation and profitability are paramount, you must take control of cyber risks by implementing an actionable plan that closes gaps, meets standards and delivers the financial and organizational efficiencies and brand impact you seek.
During this live webcast, you'll learn to:
- Adapt your security thinking to contemporary risks and attacker strategies
- Define an architecture to mitigate cyber security risks — from the oil rig to the boardroom
- Establish a stable baseline and enhance the efficiency and effectiveness of core cyber security operations
- Refocus limited internal resources from operational functions to more strategic priorities
- Confidently outsource your security functions, while maintaining real-time visibility
Join us to hear best practices from other Process Industries that are proactively addressing regulatory mandates, protecting the most sensitive enterprise data and industrial controls — through a cost effective and efficient approach. Learn how they are responding to U.S. government requirements and cyber security initiatives and how you can work with DHS more effectively.
Overview:
In September 2009, the aviation industry lauded the successful passage of a brand-new specification by the American Society of Testing and Materials (ASTM) that certifies the use of alternative jet fuels in aircraft. ASTM D7566 creates a framework for all alternatives and immediately qualifies 50% blends of Fischer-Tropsch synthetic jet fuel with conventional Jet A from multiple feedstocks including coal, biomass, natural gas and all combinations thereof. This framework will enable the passage of a range of hydrotreated renewable jet (HRJ) fuels, which are biofuels for aircraft made from a variety of feedstocks.
This specification represented the first aviation fuel qualification in nearly 20 years. So a year-and-a-half later, where are we? How far have efforts come in the commercialization of alternative jet fuels? And what are some of the challenges producers and end-users going to face?
Hart Energy’s International Fuel Quality Center and Global Biofuels Center present in partnership with FUEL magazine and Ethanol & Biofuels News a two-part series exploring the current state of the aviation biofuels industry and what’s ahead.
Session 1– Setting the Stage
• The past, present and future for aviation biofuels
• Challenges ahead
• Achieving commercialization
• Policies and incentives
Session 2– Growing the Industry
• Biofuel producers
o what they need to provide
o progress they have made
o technical developments and challenges
o reaching commercialization
• Airline buyers
o what they need from producers
o industry demands
o supply chain strategies
Overview:
Operators are working the Niobrara in several prospective basins in the region, with a good portion of the activity centered in the Denver-Julesburg Basin of northern Colorado and southern Wyoming. In this webinar, two public operators talk about their activities in the shale, and share what they have learned from their initial drilling efforts. There is still much to learn, and the Niobrara is early in the appraisal stage.
For PDC Energy, it has been encouraged by its horizontal program in the Niobrara. The company's second and third horizontal Niobrara wells in Wattenberg averaged a combined 1,004 barrels of oil equivalent per day in early production tests. This year, the operator is on pace to drill and complete eight to nine horizontal wells within Wattenberg Field and four to five horizontal wells in its Krieger area, located to the northeast.
Carrizo Oil & Gas Inc. has drilled and completed three wells in the Colorado portion of the Niobrara play. To date, it has found the completion side more challenging than the drilling side. The role of natural fracturing, the use of seismic and microseismic data, and fracturing techniques are all factors important to success. Carrizo is also encouraged by its results to date, and plans to spend $40- to $45 million in the play this year to drill 10 to 12 wells.
Overview:
In this webinar, two of the major operators in the fast-expanding Bakken play talk about their strategies and programs. Hess Corp. opened the Williston Basin in the 1950s, and it is continuing that tradition with an aggressive Bakken program. The company holds some 500,000 net acres in the play, and prides itself on a lean manufacturing approach and an advantaged infrastructure position. The company is currently running an 18-rig program, and targets production of 40,000 barrels of oil per day from the play this year. With capabilities learned in the Bakken, Hess seeks to leverage those into other regions and ultimately build a global portfolio of unconventional resources.
Continental Resources has established one of the biggest and most successful positions in the Bakken shale. Today, Continental, which drilled the first commercially successful horizontal and fracture-stimulated Bakken well in 2004, in Divide County, is the top producer in the Williston Basin. Its production expanded by 34% in first-quarter 2011 compared with the year-ago period. The company currently has 308 producing wells with 24 rigs running over its 900,000-net-acre position. It plans 151 net wells for 2011.
Overview:
This webinar features a close look at the operations of two public companies active in the Bakken play, Whiting Petroleum and Oasis Petroleum. For Whiting, the play holds tremendous upside potential. It is currently active in six areas, with Sanish/Parshall Field being the most active at this time and the Lewis and Clark area being the star on the horizon. This year, the operator will spend $707 million in the Bakken/Three Forks play. The company has 176,000 gross acres in the Williston, and its wells have been among the top producers in the basin.
Oasis Petroleum Corp. went public in June 2010 with a laser-like focus on the Bakken and Three Forks. The company operates in two distinct areas of the Williston Basin. It focuses most of its attention on the West Williston, where it holds 190,000 acres in Williams and McKenzie counties in North Dakota, and Roosevelt and Richland counties in Montana. It also holds 100,000 acres in the East Nesson. The company has been increasing its completion stages and seeing a proportionate increase in production and reserves.
Overview:
The shallow, high-permeability, high-porosity, oil- and gas-liquids-rich Mississippi Lime lies beneath some 6.5 million acres in northern Oklahoma and southern Kansas, making 1,000-barrel IPs in early horizontal and multi-stage-frac tests. Two presenters talk about the geology, economics and upside potential of this exciting Midcontinent play.
Eagle Energy began compiling acreage in 2009 and spudded its first Mississippian well in 2010. By mid-2011, the company had drilled 24 Mississippi horizontals. Low drilling and service costs, high liquids content, existing infrastructure and strong recoverable reserve volumes make the play quite attractive. Eagle Energy's recent high-rate wells include the #1H-12 Sharp, which flowed 2,600 bbl. of oil equivalent per day, and the #1 Avard 1H-31, which made 1,900 bbl. of oil equivalent per day.
Vitruvian Exploration is another private independent active in the Mississippi Lime. It notes that the outstanding economics are also due to favorable lease terms, high-quality oil, readily available water and water disposal formations. Vitruvian holds 120,000 net acres in the area west of the Nemaha uplift and 80,000 acres east of the Nemaha uplift.
Overview:
Oil-rich California offers several intriguing resource plays, including the world-class Monterey and the Kreyenhagen shales. In this webinar, two independents share their results of work to date and their plans for the future in these oil-prone plays in the Golden State.
The San Joaquin Basin's Monterey and Kreyenhagen shales are the focus of Zodiac Exploration. The basin offers plenty of data, large resource targets, and excellent reservoir potential. Zodiac entered the basin in 2009 and has expanded its portfolio to 86,221 net acres. The company has been gathering data and delineating and derisking the Monterey and Kreyenhagen plays. Zodiac is currently delving into the data to rank and assess its primary prospects. Within one or two years, the company plans to drill between four and nine vertical and one to 10 horizontal wells.
Similarly, Denver-based Venoco Inc. has had its eye on California's unconventional potential. The company has a varying set of prospects all across the state, and has accumulated 200,000 acres prospective for the Monterey, 150,000 of which are onshore. Last year, Venoco drilled test wells across its position. It has drawn the conclusion that vertical wells are currently the most effective approach to exploiting the Monterey, and it is in the midst of a major Monterey effort.
Vitruvian Exploration is another private independent active in the Mississippi Lime. It notes that the outstanding economics are also due to favorable lease terms, high-quality oil, readily available water and water disposal formations. Vitruvian holds 120,000 net acres in the area west of the Nemaha uplift and 80,000 acres east of the Nemaha uplift.
The global scene for unconventional resources has great potential, but challenges will be amplified compared with the North American story. Four leading analysts provide an inside look at some of the world’s best opportunities for unconventional resource development. The international experience will not be the same as the North American experience for unconventional gas. Although in-place resources are tremendous, such factors as equipment availability, operational efficiency, and existing infrastructure that aided the vast growth of North American unconventional production will not be as favorable overseas. Add resource estimates, market dynamics and fiscal regimes to the mix, and the challenges are considerable. Learn the latest thinking on global development of resource plays.
Three top executives—from a major, a large independent with international interests, and a North American-focused operator—talk about their strategies for success, and how unconventional resources fit into their portfolios. Major Royal Dutch Shell is bullish on gas for many reasons, and its investments show a strong commitment to developing shale resources. Shell entered the unconventional resource arena with its purchase of tight-gas assets at Pinedale in the Green River Basin in Wyoming, and followed that with 700,000 additional acres in the Marcellus shale and 250,000 acres in the Eagle Ford shale. Newfield Exploration, a mega-independent with assets in China and Malaysia, has garnered success by pursuing a diversified portfolio and focusing on margins. Newfield objectively evaluates investments and selects those most likely to be successful. This focused diversity has delivered investment flexibility. For U.S. independent SM Energy Co., success has come from a hard evaluation of company strategy. SM Energy transformed itself from a niche PDP acquirer with a large footprint to a company tightly focused on multi-pay basins and emerging plays. It also beefed up its operational and technical control by divesting non-operated properties and seeking high working interests. SM Energy’s new strategy has paid off: reserves are higher, finding costs are much lower and its multiples have improved dramatically.
Current economics, both in terms of unconventional development and on a global, macroeconomic scale, are supportive to domestic oil and gas players. Three experts discuss global markets and their interrelationship with crude oil prices, the trend of improving results in shale-gas wells, and the possibility of LNG exports from North America.
The South Texas Eagle Ford play has galloped to the front of the shale herd. Its lightning-fast growth has been driven by strong well results across wide expanses. In this webinar, three operators talk about their approaches to the Eagle Ford, and how this play relates to their activities in other unconventional plays. Petrohawk Energy discovered the Eagle Ford play in 2008, when it opened Hawkville Field. Today, the operator continues to fine-tune its completion programs, and reports good results from HiWAY fracture treatments. The company is grappling with immature infrastructure in the play, which is one of the biggest challenges. It holds 300,000 acres it considers commercially productive Private firm Laredo Energy IV stays ultra-ultra-focused on South Texas. Its strengths are landowner relationships and the ability to get acreage through those relationships. It guards its reputation zealously, and is highly engaged in the community of Laredo. The company has deep roots in South Texas, beginning with work in the complex, highly faulted Lobo Trend. Today it works mainly in Webb and Zapata counties, and drills in the Austin Chalk, San Miguel, Escondido and Wilcox, in addition to the Eagle Ford. For El Paso E&P, the Eagle Ford is a focus area. The company holds 170,000 net acres in the play, and 60% of that is in the oily area. It has four rigs at work, and to date has drilled 25 wells. In addition to the Eagle Ford, El Paso has expanded into the Haynesville and Wolfcamp shale plays. Its current programs give it much greater visibility to future growth.
Overview:
The rich-gas portion of the Marcellus play covers an area of 3,000 to 5,000 square miles--to put it into perspective, about the size of the Barnett shale play's core. Billions of dollars in investments will be needed to maximize producer netbacks from NGLs and reach markets.
At present, the Marcellus plays lacks sufficient processing and fractionation capacity, an NGL pipeline and a local industrial market. Still, while midstream companies are in the early days of solving these issues, the rates of return are present for both upstream and midstream companies, particularly from the gas-rich areas, to justify the expansions. And these hefty returns are possible even at low natural gas prices.
The Appalachian Basin now produces about 2.5 billion cubic feet of gas per day, and volumes are set to rise dramatically as more Marcellus wells are drilled in Pennsylvania. Some 2,300 shale wells have been drilled so far in the Keystone State, and the estimated resource--as much as 260 trillion cubic feet of recoverable gas--could make the play the second-largest gas field in the world.
The booming Marcellus shale-gas play brings a wealth of economic opportunities to midstream firms. Meeting the need of Pennsylvania’s natural gas producing industry will require tremendous investment in pipeline infrastructure, and that spells opportunities for many new participants.
One company that is embracing the Marcellus to become a fully integrated producer, gatherer and processor is Magnum Hunter Resources Corp. The firm is seizing Marcellus shale opportunities on its Appalachian Basin acreage, and is expanding its Eureka Hunter pipeline and processing system.
Overview:
Nowhere is the economic rebound in the midstream industry more obvious than with the market for master limited partnerships (MLP), which have returned to their pre-collapse performances and are expected to continue to grow. Recent strong returns mean that capital is flowing back into the MLP space, and investors are particularly attracted to MLPs in the Marcellus shale.
Operators have been so successful in bringing on volumes that takeaway capacity is stretched thin. Already seven midstream projects have been announced or are in development to alleviate NGL bottlenecks in the play.
To date, MLPs alone have committed more than $1 billion in infrastructure funding in the Marcellus, and that trend is expected to continue. The location, large reserve base and strong well economics in the Marcellus mean that MLPs offer an ongoing wealth of opportunities.
Overview:
Storage is a hot-button topic in the booming Marcellus play, thanks to its location near highly seasonal demand markets. But with surging gas volumes and changing market dynamics, the region needs even more storage infrastructure.
Trends in storage in the Marcellus region include continued use by large end users, such as local distribution companies and industrial customers, and addition of new power generation clients. Flexibility in pipeline and storage design is crucial going forward. At the same time, there are only a limited number of geological structures suited for storage development.
Operators are responding to the call with new facilities and plans for further expansions, and at the same time confronting issues of community and regulatory acceptance.
Overview:
Production from deepwater wells and reservoirs can be optimized through the union of reservoir modeling and simulation software with a full suite of instrumentation for downhole and subsea flow assurance and production monitoring.
Monitoring alerts operators to conditions needing their immediate attention, including accumulated information about actual production flow rates and downhole pressure and temperature, fed back into the reservoir model. This improves the operator’s understanding of the reservoir and supports important decisions such as placement of new injection or production wells.
In 2009, Roxar, a $200 million provider of instrumentation, software and modeling technology joined Emerson Process Management, a $6.5 billion unit within industrial conglomerate Emerson.
Tune into this Hart Energy Technology Management broadcast to hear Ottar Vikingstad, Director, Oil and Gas Sales and Marketing, and Randy Balentine, Delta V Product Strategist, discuss how configurable solutions that unite Emerson instrumentation, valves and architecture with Roxar multiphase flow instruments with predictive geological and engineering models can provide the benefits described above, as well as the following:
• Seamless interfaces between subsea production systems and topside control systems
• Asset monitoring to inform of potential failures or required maintenance of subsea or downhole instrumentation and equipment
• Closed- or open-loop control of subsea functions like well optimization and hydrate, corrosion or sand management
Attend this broadcast to learn how a configurable industry solution can be the means to continuously monitor production, observe and control oil and gas fields from remote locations, process large volumes of vital reservoir data quickly and use the most up-to-date field information to make critical operational decisions.
As the petroleum industry’s shift from analog- to digital-based information quickens, drill-head and equipment sensor readings are being streamed real-time to operations centers. This enhanced capability should support better drilling and production decisions.
To take advantage of these dynamic developments, two things must change. The industry’s mindset and attitude toward analytics must be such to take advantage of the wealth of opportunities presented, and the analytic “bottleneck” that limits the value of the new drilling and sensor technologies must be addressed.
Traditional data-analysis systems are quickly overwhelmed by the sheer volume of real-time data streaming into conventional databases. Without the ability to run analytics on telemetric and machine-generated data sets their value is limited.
Tune in to learn about the challenges, opportunities and benefits following from the ability to gather, manipulate and value multi-format machine-generated data, as well as its translation into business insight.
Imagine being in a 100+ year old industry where very little analytical technology has been introduced since the 1960s. Revolutionary gains in analytics are transforming many industries. Tune into the broadcast to see how analytics use will transform E&P.
The global shipping industry is under increasing political pressure to reduce emissions of air pollutants and greenhouse gases. For several years, the International Maritime Organization (IMO) has been working on tightening regulations controlling air pollutant emissions from shipping – regulations in Annex VI of the Marpol Convention. IFQC invited Donald Gregory, Director of the Exhaust Gas Cleaning Systems Association (EGCSA) to give an overview of the exhaust gas cleaning systems as well as developments and operating experience with them. This Webinar will provide you insight into the marine scrubber technology and help you understand what role it will play meeting the future marine challenges - perfect also for busy executives who do not have time to follow developments on a daily basis! The following questions are answered: What technologies exist to tackle marine emissions? How do these technologies differ? What is the payback period for the scrubber systems? What are the existing challenges for these technologies? What is their operating experience? The Webinar consists of a 30 minute presentation by Gregory and a 30 minute Q&A session. More on the Annex VI of the Marpol Convention: A revised Annex VI was formally approved by IMO in October 2008, and entered into force on July 1, 2010. Its main changes are tighter controls on sulfur oxide (SOx) emissions (via fuel sulfur limits), and on nitrogen oxides (NOx) emissions. The first impact is that the sulfur limit for marine fuels used in designated SOx Emission Control Areas (ECAs) was lowered to 1.00 wt% July 2010. Beyond 2010, Annex VI will further tighten sulfur limits both globally and in SOx ECAs. In all cases, abatement measures (such as exhaust gas scrubbing) are permitted as an alternative to using compliant fuels. More on the EGCSA: Member companies of the EGCSA are involved in the development, design and final installed configuration and design approval and acceptance of turnkey exhaust gas cleaning systems to meet the current and future emissions regulations of IMO and where applicable additional regulations introduced by regional and national authorities.
The most active of exploration and production companies are keen about the opportunities in North America, but every active operator seeks an advantage to obtain the prime leases for their projects. Some have proven more proficient than others by leveraging technology to streamline their workflow and provide a better view of what land is owned, where the gaps exist, when leases expire, and how all of this translates to accurate and timely maps and financial information. In this webinar, you will hear from a former trust attorney turned E&P partner who formerly managed a $500 MM trust business using a 5-tier accounting system about how his company manages 4 times more leaseholds than was possible with previous methods. You will also hear the experiences of a national broker who works with some of the largest E&P firms in the country.
Now more than ever, expertise in the oil and gas industry is critical. The future of the industry depends on the young professionals now entering the energy sector. “Young Professionals: Mastering Your Career in the Energy Industry” is a webinar tailored to address students and young professionals who have concerns about building a career in the oil and gas industry. From the benefits of horizontal movement to the importance of blending into a company’s culture, there are many ways a young professional can climb the ladder in the energy industry. People trust people that they know or those that are referred by someone that they know and trust. Just as it is critical to get a referral when looking for a job in a new company, it is equally important to get a referral when competing for desirable positions within your own company.
The Marcellus shale is a resource play of great potential; however, it is not uniform, and structural variations affect reservoir quality and prospectivity. Operators have found large variations in well performance and, therefore, the return on investment from individual wells. Seismic data can provide cost-effective information regarding the variations in reservoir properties, and it can be used to enhance the success of drilling programs.
While not a new phenomenon, shale plays are becoming of increasing interest as E&P companies search for alternative resources. Successful E&P operators in shales are increasingly using seismic to maximize production. Learn from leading experts how seismic can help you understand the geology of shale plays to optimize your wellbore placement and improve overall well productivity.
Register now to attend the Webinar, “The Power of Seismic – Unlocking Unconventional Reservoirs,” at 10 a.m. CST, Wednesday, September 29, 2010.
What you will learn:
- The value of seismic data in shale plays
- How operators are using seismic to enhance their productivity in shales
- How seismic data can provide information about stress fields, fractures, and rock properties
The archived version of this Webinar will be accessible from this page after the live broadcast.
This 3-panel session brings you a collection of 7 Industry Leaders discussing the following topics. Panel 1: Bakken and Three Forks/Sanish Harold G. Hamm, Chairman and CEO, Continental Resources What you will learn: Production and capacity in the Bakken Oil vs. gas production growth in the region Why the U.S. is now less dependant on foreign imports and the value of infrastructure Jim Volker, Chairman, President & CEO, Whiting Petroleum What you will learn: Rate of return based on well costs and production profile Future pipeline expansion and take-away capacity increases Previous equipment deployment and success ratios by distance Panel 2: Geochemistry, Geology & Geophysics of Oil-prone Shales Shale-oil Systems, Their Main Characteristics and Distribution Daniel M. Jarvie, President, Worldwide Geochemistry What you will learn: The benefits of using geochemistry on shale oil vs. shale gas A better understanding of the different types of shale oil systems Why fractured oil shales have the highest potential The Bakken: What We Know and What it Tells Us about Analogs Steve Sonnenberg, Professor, Colorado School of Mines What you will learn: Factors related to tight oil production Source bed plays Tight oil play examples (Bakken/Three Forks, Niobrara) Seismic Applications in Oil Shales Chris M. Friedemann, Sr. Vice President-Corporate Marketing, ION Geophysical Corporation What you will learn: The difference between gas and oil shales from a seismic perspective Methods to image shale plays Emerging technologies and techniques Panel 3: Bakken, Niobrara and Mowry Peter Dea, President and CEO, Cirque Resources LP What you will learn: Risk management in oil resource plays Recovery of OOIP, what are the drivers? Paleogeography of specific formations including the Bakken, Niobrara and Mowry Peter Loeffler, VP of Exploration and Development, American Oil & Gas Inc. What you will learn: Commercializing shale through advances in technology and revisiting previously malined areas Largest U.S. oil fields by capacity over the last century Proppant placement issues and challenges in the Bakken
This A&D panel brings you Wall Street's view of the Bakken and other oily shales.
Where the money is, the investors will follow. The Bakken and Monterey shales have given us inspired hopes,
but where do we look next for future investments?
In this session you will hear views from Wall Street, as well as an A&D inside look on the oily shales
Wall Street's View of the Bakken and Oily Shales What you will learn:
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An A&D View on Oily Shales From an Industry Insider What you will learn:
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BONUS CONTENT - JUST ADDED
Oil and Gas Investor's editor-in-chief Leslie Haines' Q&A with Subash Chandra
Rick Moncrief, Pres. and COO, Caiman Energy II, LLC; Dennis McCanless, Mgr. Director, EnCap Flatrock
ADAM Houston sponsors golf tournament
JOIN US FOR A DAY OF GREAT GOLF AND A&D NETWORKING FUN!
TopGolf Houston West 1030 Memorial Brook Blvd, Houston, Texas 77084 281-406-3176
www.topgolf.com
Wednesday, June 5th, 2013 11 a.m. – registration 12:0pm – play begins 3:00pm – Awards (located on the 2nd level) ANYONE CAN PLAY!
No golf experience necessary. If you don’t have golf clubs, TopGolf will provide them!
What’s Included: 3 hours of game play (peak hours), lifetime membership card, food & drinks, great networking! Price per Player: Limit of 200 players ADAM-Houston Members: $150.00 Non-Members: $175.00 ENTRY DEADLINE: FRIDAY, MAY 24TH
Glynn Roberts President & CEO, Northstar Offshore Group LLC, "Operating in the Shallow Gulf Today"
ADAM-Houston
Date: June 1, 2009 - June 3, 2009
Location:
Intercontinental Hotel
2222 West Loop South
Houston, Texas, U.S.A
Here’s the money! Oil and Gas Investor’s Energy Capital Forum is the must-attend instructional and networking forum for E&P and other energy executives and technical personnel seeking in-depth discussion of funding trends and forecasts for future capital access. The emphasis here is information that is practical, immediately translatable to finding funds, and profitable.
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Energy Network–The Woodlands
Houston Energy Finance Group
IPAA Tulsa Leadership Luncheon
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