E&P companies are seeking solutions to understand geologic subsurface formations that are often deeper and more complex than ever before. Whether in shale, oil sands or even shifting salt formations, it is the job of geologists and geophysicists to locate, tap and extract the last of every reservoir to maximize the large investments their companies have made. In order to support these efforts, technologies that produce higher data quality and richer characterization of the earth's surface are in need.
Every well presents unique challenges and each customer has specific goals and objectives. The Sperry Drilling team understands the customer’s challenges and goals, and engineers the best solution, combining know-how and skill with emerging technologies to make the customer successful. Our new Quasar Pulse™ 200C M/LWD sensors are at the leading edge of data-acquisition technology. The XBAT™ Azimuthal Sonic and Ultrasonic LWD Service features the latest in sonic technology. The GeoForce® XL/XLS motor is the toughest drilling motor on land. These are just a few of the advanced services and products that help Halliburton build the right solution for every challenge.
As data and compliance grow, it is more important for oil and gas organizations to actively manage their full range of endpoints. In this webcast, Dave Womack explains why managing endpoints is crucial in the oil and gas industry. Dave explains endpoint and security management in a nutshell and how this enables your team to see and manage physical and virtual endpoints—servers, desktops, handhelds. and specialized industrial control equipment.
In our first webinar series entitled “What Broadband Land Seismic Technology Means to Your Project’s Success,” we examined how advances in acquisition technology provide operators with the tools needed to acquire high quality, broadband data in a cost-effective manner. We also looked at how E&P companies benefit from seismic technologies that record broadband data to capture wide azimuth, tightly sampled data with more octaves to substantially improve processing and interpretation techniques such as full waveform inversion.
This is the third of three webinars about NESHAP Subpart ZZZZ. New regulations go into effect in less than 60 days. Is your company ready for the October 19 deadline? In this webinar, world leaders in independent E&P and natural gas compression will share their approaches to NESHAP ZZZZ compliance. You’ll get to compare notes with Anadarko and Exterran, and benefit from their perspectives.
This is the second of three webinars about NESHAP Subpart ZZZZ. On October 19, 2013, new regulations go into effect for National Emissions Standards for Hazardous Air Pollutants (NESHAP) Subpart ZZZZ. This webinar will cover regulatory implications of the new regulations, including enforcement and risk minimization for spark-ignited reciprocating internal combustion natural gas engines (SI RICE).
Interested in learning how technology is accelerating and increasing accuracy for seismic interpretation and depth imaging workflows? Attend this webinar to learn how Seismic Ventures uses a combination of innovative software and hardware technologies from TerraSpark Geosciences, HP, and NVIDIA to achieve optimal results.
E&P companies are seeking solutions to understand geologic subsurface formations that are often deeper and more complex than ever before. Whether in shale, oil sands or even shifting salt formations, it is the job of geologists and geophysicists to locate, tap and extract the last of every reservoir to maximize the large investments their companies have made. In order to support these efforts, technologies that produce higher data quality and richer characterization of the earth’s surface are in need.
On October 19, 2013, new regulations go into effect for National Emissions Standards for Hazardous Air Pollutants (NESHAP) Subpart ZZZZ. This webinar will review the impact on management and operation of all spark-ignited reciprocating internal combustion natural gas engines (SI RICE).
Big Data means big opportunity to create business value in your E&P workflows. EMC Isilon is leading the way with scale-out NAS solutions purpose-built to solve the performance, capacity, and application consolidation challenges presented by massive amounts of file-based upstream data. Think about the challenges you face today and how they will grow in the future. E&P is a complex business that requires tremendous information technology resources to be successful. Big Data is not just about massive seismic datasets, either. Think of the many data types and formats you use -- geophysical, geological, petrophysical, drilling, and production datasets -- plus all the different upstream applications you use in the process of discovering and producing hydrocarbons. There is large volume and wide variety. As exploration complexity rises, risk increases,and the amount of data you use grows. Plus, there is always pressure to provide answers faster.
As oil and gas become harder to find, new techniques are being developed to "see" deeper, see under salt, and understand more clearly what is happening with subsurface prospects. This has led to massive growth in dataset sizes and computational needs.
With rising costs of infrastructure, reduced IT budgets and the increasing disparate workforces, E&P companies are being challenged to investigate alternative capabilities. Landmark's Cloud Services addresses these growing challenges and costs.
Our industry is faced with unprecedented complexity and data growth. The challenges come in turning this data into knowledge and insights?and then making those insights available to the right people in shorter time-frames, wherever they are.
Hart Energy introduces the "Big Data and the Cloud" webinar series that brings together leaders from the industry and the information technology sector to discuss the latest trends and innovations that will reshape data centers forthe oil and gas industry.
Join NetApp, NVIDIA, Paradigm and Cisco on Sept 27 for the first webinar which will focus on enabling remote interactive 3-D visualization to facilitate effective global collaboration.
Hart Energy, along with P2 Energy Solutions, will show you how to revolutionize your Tobin Map Data. Today, companies spend hours downloading and compiling data before it becomes usable data for making decision that drive your business.
P2 now offers Tobin Online, which provides easy access to the data you need. During NAPE, Richard Mason will moderate a discussion with Rebecca Hubis, P2's Tobin Online Data Specialist. The online product will also be demonstrated.
There is a lot of uncertainty over prices heading into 2012. Will crude prices surpass $100 per barrel? Will liquids prices be able to continue their winning streak? Can gas prices rebound? What regions have the most untapped potential for production and demand? What infrastructure projects have the potential to change the outlook for prices? This 55-minute webinar will include a live Q&A.
The Eagle Ford shale play in South Texas has plenty to offer, and activity has grown rapidly in a very short time. But operators are still coming to grips with its complexities. Geologists, geophysicists and engineers are intently studying this prolific formation, from nano-scale investigations of its porosity to its natural fractures to its response to hydraulic stimulations. Learn from the experts in this webinar, complied from some of the top technical talks at Hart Energy's 2011 DUG Eagle Ford Conference & Exhibition.
Will your company’s drilling knowledge walk out the door with your retiring workers? How will you train the next generation in oil and gas? Especially in shale, drilling a well is more complex than it has ever been. At the same time, scores of experienced oilfield workers are set to retire in the next few years. Together, it’s a combination that could do more than just make it hard to hire good people – it could seriously affect the one factor that will separate the winners from losers in shale drilling: Cost control.
But it’s not too late for prevention. With new technology, companies are taking steps to make sure this knowledge that used to lie within the heads of their experienced employees is being retained in house.
As oil and gas companies race to develop U.S. shale plays, containing their costs will be the key to success in the face of volatile commodity prices. Many E&P companies are leveraging technology to provide the visibility they need to realize true cost savings as the oil and gas industry moves toward a manufacturing mindset
From business intelligence to supply chain management, the so-called digital oilfield is coming into maturity. Companies of all sizes, from start-ups to super majors, can take advantage of technology and realize productivity improvements.
Eagle Ford Rock Talk: Geology and Geophysics Panel The Eagle Ford is a marvelous source/reservoir rock, rich in total organic carbon. It's also chock full of carbonates, which makes it amenable to hydraulic fracturing. Thanks to steep dips, the rock transitions quickly through the oil, wet gas and dry gas windows, offering a variety of targets to eager operators.
Bruce A. Matsutsuyu, VP of Exploration and Development, Momentum Oil & Gas LLC
Peter Duncan, President, Microseismic Inc
Dr. Norman Warpinski, Director of Technology, Pinnacle - A Halliburton Service
This webinar was recorded at Hart Energy’s DUG Eagle Ford 2011 Conference & Exhibition in San Antonio on October 11, 2011
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.
The Eagle Ford play in South Texas has exhibited stunning growth in its short history, and that growth continues unabated. With aggressive operator drilling schedules, it is possible for Eagle Ford production to exceed 5 Bcf per day in 2020. Opoku Danquah, Director, Upstream Research, discusses the metrics of the Eagle Ford shale, the top producers, their acreage positions, and the reasons this prolific play has a bright future ahead. Against the backdrop of the Eagle Ford success story, Richard Mason, Chief Technical Director, Upstream, will review drilling activity patterns in U.S. unconventional plays, and talk about market drivers and constraints. The industry is in the midst of a landmark shift in gas versus oil drilling, and Mason will talk about the dynamics of this historic change. The 55-minute webinar will include a live Q&A moderated by Peggy Williams, Director of Hart Energy's Unconventional Gas Center, on Tuesday, June 14 at 10 a.m. CDT What You Will Learn: Why the Eagle Ford shale play has risen to the top of U.S. unconventional targets Which operators hold the most acreage, and how those holdings are distributed across the oil and gas windows The changes currently occurring in drilling activity across unconventional plays What factors will influence second half 2011 activity
The Permian Basin of West Texas and southeast New Mexico is one of the premier U.S. producing provinces. Although its conventional reservoirs are heavily developed, today’s unconventional prospects offer attractive targets to long-time players and new entrants alike. Such unconventional plays as the Wolfberry and Bone Spring are enjoying surging activity, thanks to operators’ successes with application of the latest drilling and completion techniques. Here, in the webinar “The Permian, Petroleum and Unconventional Activity ,” you will hear the latest insights on Permian metrics and drilling activity from two industry experts.
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.
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.
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.
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.
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. What you will learn: • Opportunities for analytics use in drilling and production • Platforms for advanced analytics and data retention • How to encourage better-quality data use in your company
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.
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.
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.
Of the Marcellus play’s current production, between 15% and 35% requires processing. Economics in the play are strong, helped by both the strength and quality of the wells and the proximity of the play to the premium gas markets of the Northeastern U.S. Challenges are great, however. From a midstream perspective, fragmented acreage means that communities can be crisscrossed with several proprietary gathering systems. Too many construction projects can alienate residents, and can also lead to sub-optimal designs. At the same time, the numerous operators mean that midstream companies have many potential shippers to serve, and they can aggregate to gain economics of scale. Hear about the potential—and challenges—of the Marcellus play from the midstream perspective.
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.
What You Will Learn: How these operators are increasing leaseholds faster while reducing cost Why centralizing project information does more than eliminating the chaos of paperwork and spreadsheets What the merits of real time information really are, including the linkage to create maps How a new legion of landmen bring a competitive advantage to the field Overview: 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.
With the rapid growth in North America’s unconventional shale market, more industry players are eyeing analogous plays abroad. Although somewhat more challenging, Europe presents future promise as an unconventional gas market. China and Australia are hopeful contenders as well. As with conventional resources, the most valuable asset companies can acquire is new information on these areas. “Unconventional Shale: An International Perspective” is a webinar tailored to identify global shale gas potential and to discuss some of the challenges involved with producing these resources. From access to field development, bringing unconventional plays online within the next 5 to 10 years will require a concerted effort. Knowing where to look is the first step. Join this expert panel of analysts as they share the latest information on global shale gas potential. What you will learn: Where are the world’s largest deposits of unconventional gas? What are the recoverable reserves for these regions? What do we know about working in these regions? What challenges will exist? What is the outlook for unconventional gas within the next five to ten years?
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. What you will learn: What is the future of energy talent? Where will the talent come from? What technical training will be most desired? ??Once a young professional reaches the industry, how does he or she build a career within a company as well as moving to a new company? Is energy technology the critical skill? If so, what does it mean to the university programs and students today and later?
A year ago, energy investor and entrepreneur T. Boone Pickens launched The Pickens Plan, his ambitious national campaign to push more natural gas and other domestic energy supplies. His Pickens Army now numbers some 1.5 million people.
After spending $60 million, meeting with Obama and Pelosi, and making hundreds of appearances, has Washington gotten the message?
Join us in this webinar to find out. In a prerecorded interview Pickens talks with Leslie Haines, editor-in-chief of Oil and Gas Investor, and shares his thoughts. Topics include how the Pickens Plan may affect energy bills in Congress, Pickens’ oil and gas price outlook, what’s next for him, and more.
Even as natural gas producers and their capital providers struggle to survive in a time of recession-driven low prices, a new threat looms on the horizon. A flood of new liquefaction capacity will come online in 2009 and beyond, driving spot-cargo carriers to search for willing terminals and storage facilities. In this compelling, 50-minute webinar on Wednesday, July 8, at 10 a.m. CDT, a panel of experts will talk about their expectations for near-term imports, the possible effect on gas prices and strategies to turn threat into opportunity for all stakeholders.
Keith O. Rattie, chairman, president and chief executive officer of Salt Lake City-based integrated gas company Questar Corp. and a past chairman of the Interstate Natural Gas Association of America discusses the various sources of energy today, carbon policy and how natural gas plays a role in the energy future in this approximately 60-minute webinar.
The Appalachian Basin’s Marcellus shale is one of the top shale plays in the world, and recent strong well results from several operators working in widely spaced areas show the Devonian shale is living up to its promise. Its excellent reservoir characteristics, vast areal extent and position in the core of North America’s premium natural-gas market make it a viable play even in these difficult economic times. This webinar will look at microseismic and passive seismic use in the play; an operator’s view of play upside, economics and gas marketing issues; and at areas under development, expected decline curves and reserves.
There’s a backlash to shale play activity in Texas. The current session of the Texas legislature is focusing on gas pipeline regulation more than ever before. While compromises that satisfy both industry and the public are possible, nothing is certain. And the sheer volume of Barnett activity has prompted Fort Worth to redraw and review its ordinances. Other Texas municipalities may follow, but may not be as friendly to pipelines and producers.
The bottom line is that some statutory changes may curtail activity and make shale development more expensive.
Southeastern Oklahoma’s Woodford shale and north-central Arkansas’ Fayetteville shale plays hold trillions of cubic feet of gas in place, and producers are engaged in massive drilling programs to tap the resources. These two shale plays continue to attract drilling dollars, thanks to operators’ success in pushing well costs downward and ultimate recoveries upward. This webinar will look at the superb source-rock characteristics of the Woodford and Fayetteville shales, offer an activity round-up, and delve into the use of microseismic in Woodford shale well completions.
A copy of the Arkoma Playbook is complimentary with your registration.
The oil and gas industry is collecting massive amounts of sensor data from operations spanning exploration, drilling, and production. The velocity and complexity of data growth has put immense strain on application and database performance not to mention skyrocketing data storage costs. This rapid growth necessitates a fundamental change to the way data is collected, stored, analyzed, and accessed to support real-time intelligence and decision making.
One of the largest obstacles to time-to-oil today is in the tremendous increases in the amount of data used and generated in support of a single project. How can you build a faster time to oil when you generate, capture, transfer, store, process and analyze data to get answers faster?