Efficiency and uptime are key across all industries, but especially so in E&P where safe and secure operations are critical. Increasingly more of those operations utilize hardware and software solutions to communicate between the field and office. This increased application use coupled with high volume of server requests place an increased burden on shared storage resources that adversely impact application performance. One way to overcome these storage bottlenecks that degrade application performance in virtual environments is through the use of high speed server resources like flash storage. By putting storage performance on the server tier, companies can accelerate virtual workloads while extending the life of existing storage assets. 

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This webinar will explore the interfaces, server appliances, integration and configuration of flash storage, consider the advantages and limitations of PCIe, SAS and SATA, and show how SSD’s reliability, performance, data integrity and direct application access break the I/O bottleneck for massive performance and productivity gains over HDD.

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  • How can you accelerate your time to oil?
  • What do you need to know about scalable computing with the Intel Xeon Phi?
  • How can you remove the obstacles that can slow your processing?

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?

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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.

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Many factors must be considered in prospecting for unconventional plays. Join experts from DrillingInfo in this complementary webinar that will focus on how to do in-depth analyses that will enable you to make the best business decisions going forward.

The first step in prospecting is targeting, where explorers identify broad areas of opportunity. A review of expiring leases and permitting and drilling activity lays the foundation for more intensive investigations. Building on that, data on production rates, peak rates, well costs and ultimate recoveries firm up the economic picture for particular plays, and particular areas within specific plays.

Once an area of interest is defined, a detailed subsurface picture is established by interpretation of well-log information and integration of production rates and geological characteristics into a cohesive whole. This selection processes results in delineation of prime areas for drilling.

When an unconventional play is under development, best practices are crucial. The webinar experts will show how data on well completion strategies can be leveraged, and how optimum well spacing can be determined. The implications of casing programs, choke sizes, completion strategies and lateral lengths on results will be discussed, and how these data can be used to help make the best business decisions.

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  • Geologic and operational insights into the Eagle Ford Shale
  • Learn how refined data and solutions can better support critical business decisions
  • Combining geologic and operational variables to statistically drive decisions in unconventional resources
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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.

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Rapidly-growing seismic data volumes and increased use of pre-stack gathers continue to complicate seismic data management, delaying interpretation. Self-Service Seismic can help companies access and harness seismic information rapidly to reach the insight required for well-informed interpretation decisions.

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How 3-D image-based petrophysical properties such as porosity, permeability and wettability impact recovery and contribute to the faster development of a more accurate reservoir model.

When lab results and log measurements are inconsistent, inconclusive or conflicting, it can be an ‘all hands on deck’ exercise to unravel the data and get to the truth.  However, in many cases the necessary data points such as wettability, capillary pressure and relative permeability can be months, if not years, away from input to the reservoir model.  Guesstimates can lead to over- or under-inflated evaluations of recoverable hydrocarbons and can greatly impact production predictions – ultimately compromising decision-making that effects CAPEX investments in downstream infrastructure.
Digital rock is a relatively new discipline that advances traditional core analysis by using high-resolution microscopy imaging systems and 3-D visualization techniques to analyze the microstructural rock features of core samples. Using process- or image-based modeling, digital rock creates an accurate representation of the pore-scale internal rock architecture in 3-D by incorporating micro- and nano-scale structures such as grain size, contact angles, pore network connectivity, mineralogy, and clay content (to name a few). The models can be used to generate multi-phase fluid flow simulations that provide advanced rock and fluid properties in less time than traditional measurements – a first look at the dynamics contributing to ultimate recovery.
In this webinar, you will: 
•    Learn about digital rock modeling and how simulated multi-phase flow properties can deliver answers faster and with greater insight than traditional measurements.
•    Discover the many instances where digital rock analysis can provide answers which are either difficult or impossible to obtain by more conventional methods.
•    Understand how the combination of imaging and pore-scale modelling can lead to more accurate estimates of properties like residual hydrocarbon saturations.


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How your company responds to change can mean the difference between delays and cost overruns, and projects being completed on schedule and on budget.

Join Oracle and the Economist Intelligence Unit for a webcast and learn best practices and how other project owners in the oil and gas industry are managing change.

What you will learn:

  • Govern project and program compliance and regulatory requirements for project success
  • Unite project teams and stakeholders to speed project completion
  • Reduce the risk of cost and schedule overruns and deliver on time and on budget
  • Effectively manage change throughout the project
  • Ensure sufficient capacity, utilization, and availability to meet commitments.
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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.

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The first of three sessions from 2010 Developing Unconventional Oil (DUO), this presentation includes three panels: Bakken and Three Forks/Sanish; Geochemistry, Geology & Geophysics of Oil-prone Shales; and Bakken, Niobrara and Mowry. Registrants for this session can also purchase the entire DUO series that includes 17 spearkers and over 6 hours of content for an additional $50.

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