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  • Advances in Sensor Technology Research to Support Drilling Automation

    Contains 3 Component(s), Includes Credits Includes a Live Web Event on 12/10/2019 at 9:30 AM (EST)

    The University of Texas at Austin has been working on advanced sensor technologies over the last 6 years in a bid to improve the safety and efficiency of drilling operations, and to reduce uncertainty with regards to data and situational awareness.

    The University of Texas at Austin has been working on advanced sensor technologies over the last 6 years in a bid to improve the safety and efficiency of drilling operations, and to reduce uncertainty with regards to data and situational awareness. The sensor technologies include a cuttings transport sensor, an X-Ray densitometer, an automated rheometer and a bit box sensor. All these sensors are enabled by recent advances in hardware and software technologies. This presentation will introduces all the four technologies, their working principles, the prototypes built and results from field trials. These sensors are expected to play a big role as we move towards drilling automation.

    All content contained within this webinar is copyrighted by Dr. Pradeepkumar Ashok and its use and/or reproduction outside the portal requires express permission from Dr. Pradeepkumar Ashok.

    Dr. Pradeepkumar Ashok

    Senior Research Scientist, Rig Automation and Performance Improvement in Drilling (RAPID) Group, UT Austin

    Dr. Ashok is a PhD in Mechanical Engineering and a Senior Research Scientist in the Rig Automation and Performance Improvement in Drilling (RAPID) Group at UT Austin. He is also the CTO of a startup Intellicess that was spun out of UT to commercialize a technology that allows one to differentiate between sensor and process faults. Previously he was the Program Manager and Chief Scientist of the Robotics Research Group at U.T., where he managed automation projects funded by ONR, NASA, DARPA, John Deere, Union Pacific and Intuitive Surgical. He has authored many publications on sensor data fusion, decision theory, automation and controls. He directs the drilling data analytics student program at UT.

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  • Complete the Machine Learning Life Cycle with Production Deployment

    Contains 3 Component(s), Includes Credits Includes a Live Web Event on 12/05/2019 at 1:00 PM (EST)

    The talk will focus on the next crucial steps to operationalize a successful Machine Learning pilot. In order to start capturing business value of a model for competitive advantage, it needs to be effectively deployed into production.

    Machine Learning is one of the biggest value generator in Analytics in the recent years. The data science workflow for machine learning models has started to extend beyond evaluations and there is an increasing demand to set up models at scale in production.

    The talk will focus on the next crucial steps to operationalize a successful Machine Learning pilot. In order to start capturing business value of a model for competitive advantage, it needs to be effectively deployed into production. It is important for every decision-maker to understand how Machine Learning Model production deployment and support work and how to reduce the risk of failure to sustain a Data Science solution.

    All content contained within this webinar is copyrighted by Tamas Toth and its use and/or reproduction outside the portal requires express permission from Tamas Toth.

    Tamas Toth

    Upstream Data Science Supervisor, ExxonMobil

    Mr. Toth is the Upstream Data Science Supervisor for ExxonMobil as a member of ExxonMobil IT (EMIT), Data Science & Analytics organization. In his role he is responsible for the day-to-day operations of the EMIT Upstream Data Science group. As Data Science Supervisor, he organizes and facilitates business critical engagements and leads the Data Science culture change within ExxonMobil. He oversees autonomous teams including employees, contractors, third parties, and contacts in academia in developing and implementing new and emerging solutions. 

    The EMIT global Data Science & Analytics organization, Data Science group is a multidisciplinary team of technical professionals who work closely with research and business units to discover, develop, and apply cutting-edge computing technologies and tools for solving ExxonMobil’s toughest energy challenges. 

    Previously Mr. Toth assumed the Analytics Architect position in ExxonMobil IT Strategy, Architecture & Technology (A&T) organization. In this capacity, he provided strategic application architecture direction and roadmap for implementing analytics solutions at ExxonMobil.

    A&T establishes and manages IT direction, architectures, and IT standards for ExxonMobil and monitors technology trends to determine which technologies are providing enough benefit for an early use. 

    Mr. Toth has been employed with the word wide operations of ExxonMobil Corporation since 2004. In a career spanning 15+ years, he has held technical and managerial positions in IT units covering Data Science, Analytics, Data Warehouse management, supporting UNIX environments and established Process Automation services. 

    Mr. Toth obtained a Bachelor of Science in Information Technology and advanced degree in Business Management.

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  • Fracpack Anomalies and Its Impact on Productivity in Deepwater Wells

    Contains 3 Component(s), Includes Credits Includes a Live Web Event on 12/05/2019 at 9:30 AM (EST)

    Fracpacking and fracturing are well established techniques carried out for sand control and production enhancement respectively. This talk will focus on typical anomalies that may be encountered during pre-fracture diagnostics and discuss tactical strategies to either delay the pumping treatment to establish a better connectivity or set expectations on treatment and productivity outcomes when these anomalies are noticed via case histories.

    Fracpacking and fracturing are well established techniques carried out for sand control and production enhancement respectively.  Recent work on fracture perforations (perforations in the fracture plane) and off-plane perforations (perforations not aligned with the fracture plane) has highlighted the importance of all perforations in terms of fracture and reservoir connectivity. Depending on the reservoir permeability, perforation shot density and near wellbore fracture alignment with the preferred fracture plane, the production load is always shared between the fracture and perforations and can potentially affect overall productivity.  However, the connectivity aspect is often ignored during pumping operations,that can result in sub-optimal fracture placement.  This talk will focus on typical anomalies that may be encountered during pre-fracture diagnostics and discuss tactical strategies to either delay the pumping treatment to establish a better connectivity or set expectations on treatment and productivity outcomes when these anomalies are noticed via case histories.

    All content contained within this webinar is copyrighted by Karthik Mahadev and its use and/or reproduction outside the portal requires express permission from Karthik Mahadev.

    Karthik Mahadev

    Wells Fracturing and Stimulation Advisor, BP

    Mr. Mahadev is the BP Wells Fracturing and Stimulation Advisor accountable for planning, design and delivery of fracpacks and stimulation treatments across BP, primarily in an offshore/deepwater environment.  Karthik’s expertise are in the areas of Fracturing, Stimulation, Sand Control, Interventions and Formation Damage and has worked the entire gamut of BP Gulf of Mexico’s Deepwater portfolio in these areas.  He also serves as a Cased Hole Fracpack Design Instructor at BP’s Sand Control Advanced Development Program. Prior to joining BP in 2009, Karthik was Pumping Product Line Manager at (CSI Technologies) Superior Energy Services Karthik started his career at Baker Oil Tools in 1998 as a Region Engineer.

    Karthik holds a B.S. in Chemical Engineering, an M.S. in Petroleum Engineering from the University of Oklahoma and an MBA in Finance and Competitive Strategy from the Bauer College of Business, University of Houston.  Karthik serves in the several SPE ATCE Committees and study groups.  Karthik is a member of Beta Gamma Sigma, Honor Society for Business and Pi Epsilon Tau, Honor Society of Petroleum Engineering.

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  • Causes for Cement Plug Failures and Proactive Measures to Maximize Success

    Contains 3 Component(s), Includes Credits Includes a Live Web Event on 11/21/2019 at 9:30 AM (EST)

    It is quite well known within the Industry that cement plug placement and its success in the first attempt is challenging. There are multitude of reasons for failures, such as improper hole cleaning, lack of adequate support for the cement plug, placement techniques, inadequate volume etc. T

    It is quite well known within the Industry that cement plug placement and its success in the first attempt is challenging. There are multitude of reasons for failures, such as improper hole cleaning, lack of adequate support for the cement plug, placement techniques, inadequate volume etc. This presentation will aim at first understanding the main challenges and causes of failures and then provide guidance on best practices to minimize failures and maximize success. It will encompass Fluid selection, placement techniques and use of softwares so that a comprehensive approach can be adopted as recommendations to address these challenges to minimize the risks of failures.

    All content contained within this webinar is copyrighted by Deepak Khatri and its use and/or reproduction outside the portal requires express permission from Deepak Khatri.

    Deepak Khatri

    Product Line Director, Cementing, Baker Hughes

    Mr. Khatri has a total of twenty-two years of industry experience, spread across the Middle East, Europe, Africa and North America. He has worked primarily in oil well cementing and has specialized in the areas of Technical support, design, execution, evaluation of cementing jobs including business and training in relation to cementing. He holds a BS in Mechanical Engineering from Bombay University and a Masters’ in Business Administration from Oklahoma State University. To his credit, he has co-authored SPE papers and has published oil well cementing related articles for trade shows. He has delivered presentations at SPE and other Industry Leading Forums.

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  • CO2 in the Subsurface - From EOR to Storage

    Contains 3 Component(s), Includes Credits Recorded On: 11/19/2019

    Presented by Dr. Gary Teletzke

    The Intergovernmental Panel on Climate Change (IPCC) and the International Energy Agency (IEA) have issued recent reports suggesting that deployment of carbon dioxide capture and storage (CCS) can significantly reduce the cost of achieving CO2 emission reduction targets.  However, several questions remain: Under what circumstances will large-scale deployment take place? Where and when will this occur? How large a role will CCS play in stabilizing atmospheric concentrations of CO2? I will review the current status of CO2-EOR and geologic storage focusing on subsurface lessons learned and their implications for large-scale CCS.

    Our industry has a long history with CO2-EOR that provides a strong experience base for CO2 storage. However, CO2-EOR alone will be insufficient to meet emission reduction targets and storage in deep saline aquifers is also being investigated.Experience from operating CCS projects shows that subsurface storage capacity in saline formations can be limited by dynamic injectability factors. Hundreds of years of CO2 storage capacity is potentially available, even after accounting for dynamic limitations, but the areal distribution of potential storage capacity is widely varied. Geologic and reservoir engineering studies will be essential for identifying storage sites having adequate capacity, containment, and injectivity. Petroleum engineers will play a key role in these studies.

    All content contained within this webinar is copyrighted by Dr. Gary Teletzke and its use and/or reproduction outside the portal requires express permission from Dr. Gary Teletzke.

    Dr. Gary Teletzke

    Senior Technical Advisor, Enhanced Oil Recovery, ExxonMobil Upstream Research Company

    Dr. Teletzke has led research projects related to gas injection EOR, chemical EOR, and compositional reservoir simulation. He has also led several EOR field studies, integrating laboratory work, reservoir simulation, and pilot testing. For the past ten years, he has provided technical leadership to research efforts on CO2 sequestration. He has published more than 40 technical papers and patents. He has organized numerous SPE conferences over the past two decades and served as Executive Editor of SPEREE from 2015-2017. He was named an SPE Distinguished Member in 2013. He received a BS in chemical engineering from Northwestern University and PhD in chemical engineering from University of Minnesota.

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  • Community Health and Wellbeing: a Pillar of Responsible and Sustainable Projects

    Contains 3 Component(s), Includes Credits Recorded On: 11/13/2019

    Public health integrates occupational and community health initiatives to enhance the wellbeing of its workforce, their families and the communities. Speakers present internal process for identifying and managing health impacts.

    This webinar consists of four sections:

    #1 - Introduction of the issue of community health and its determinants.

    #2 - Case Study 1 - In the recent years, IOGP Companies mission are focusing not only on energy but also on a possible role in sustainable development of partner countries recognizing, in the general objective of the socio-economic development, the promotion of social/health welfare as an essential requirement. In this regard, a HIA (or ESHIA) could provide the opportunity to widen the situation analysis beyond the Industrial area of influence, and impacts mitigation purposes, converging on Public Social/Health needs of a given population in their wider administrative and/or territorial context. Therefore, the results of HIA could easily provide “food for thoughts” and the opportunity of integrating mitigation plans with wider and comprehensive Community Health initiatives, for instance, in a District or Province. Eni, based on its best practices, will present their internal process for identifying and managing health impacts as part of their ESHIA system and will illustrate its possible advantages and experience of this approach.

    #3 - Case Study 2 - Public health at BP integrates occupational and community health initiatives to enhance the wellbeing of its workforce, their families and the communities where BP operates and lives through collaborative, sustainable programs aimed at: facilitating access to care; building capacity and capability; communicating risk and promoting responsible science. BP will present a case study developing a public health strategy for BP business in Angola. It will provide an overview of the community investment strategy in Angola with a focus on framework used to enhance interface and provide synergies between different sectors (private, public, third sector) in regards to public health initiatives and social performance agendas to reduce duplication of efforts and maximise benefits.

    #4 - Panel Discussion

    All content contained within this webinar is copyrighted by Yina Xiao, Delya Sommerville and Joyce Jose and its use and/or reproduction outside the portal requires express permission from Yina Xiao, Delya Sommerville and Joyce Jose.

    Yina Xiao

    Regional Health Advisor and Eni Foundation Myanmar Project Team Leader

    Yina is currently working as regional health advisor in Eni Far East region and Eni Foundation Myanmar project team leader, based in Yangon, Myanmar. She is specialized in public health project management and HIA in developing country setting. She provides supervision for the Health Impact Assessments (HIA) since 2013, which the company conducts in multiple geographic regions in both the project and strategic level. She was involved in the oil & gas industry HIA guideline revision led by the company. At the moment, Yina also co-chairs the Health Section of International Association for Impact Assessment (IAIA), as leading global network on impact assessment.

    Delya Sommerville

    Public Health, Health Informatics and Systems Director, BP

    Delya works in BP’s corporate health and leads a team managing global health systems, health performance data analysis and public health. Her previous health roles at BP included managing health programs in Azerbaijan, Georgia, Turkey and the UK. Delya’s professional focus is on digital health and broader public health issues. She is passionate about health impact assessment processes within the industry. She lives in Washington DC with her family, and is focusing on completing her part time doctorate at Johns Hopkins University School of Public Health.

    Joyce Jose

    Senior Communications Advisor, BP

    Joyce is responsible for curating, creating and planning delivery of internal communications content across BP North Sea region, in line with continuous improvement plans. Her previous role as Sustainability Manager in Angola included managing and implementing the community and social investment portfolio in support of BP´s activities in the country. Joyce is experienced in delivery of participatory social research and events management in Angola and the UK. Her main interests include working in strategic planning, developing monitoring and evaluation frameworks and volunteering in mentoring schemes for youth as well as disaster and humanitarian initiatives.

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  • Making the Right Selection (Coalescer vs Filter‐Separator)

    Contains 3 Component(s), Includes Credits Recorded On: 11/12/2019

    ​The selection of a natural gas pipeline filter is a simple task that is as easy as selecting a valve,flange gasket, or any other commodity product. Almost nothing could be further from the truth!

    The selection of a natural gas pipeline filter is a simple task that is as easy as selecting a valve,flange gasket, or any other commodity product. Almost nothing could be further from the truth!

    Gas phase filtration and separation is a mature science. It is very predictable when contaminant species are known and exist at a relatively constant concentration. Predictable contaminant conditions are rarely experienced in natural gas pipelines. Natural gas pipelines can contain condensed hydrocarbon liquids, produced water, reservoir and well completion solids, pipeline degradation solids, well head chemicals, pipeline treatment chemicals, processing chemicals, and compressor lube oils just to name a few. Two or more of these contaminant species will commonly mix and create contaminant mixtures that can be challenging to remove. Pipeline contaminant concentrations can be drastically changed by the separation effects of elevation changes and by processing equipment upsets. Equipment application standards do exist. However, navigating these treacherous separation waters will commonly prove to be a stressful experience.

    One of the most common decisions faced is the choice between selecting a gas phase filter-separator versus a gas phase coalescer. The contents of this presentation are being made available to help provide clarity and reduce the stress a little. Parker Hannifin’s Industrial Process Filtration Division (responsible for PECO brand products) has completed extensive controlled‐environment pilot tests to compare the two technologies. Data from the pilot tests will be reviewed to uncover important operational aspects. A simple understanding of how the two technologies operate will hopefully help readers with future equipment selections.

    All content contained within this webinar is copyrighted by David Burns and its use and/or reproduction outside the portal requires express permission from David Burns.

    David Burns

    Industrial Process Filtration Division Engineering Manager, Parker Hannifin

    Mr. Burns holds a Bachelors of Science degree in Natural Gas Engineering from Texas A&I University.  He is named as primary or co-inventor on 11 filtration related patents with 5 patents currently pending. David has 30 years of filtration design, application, troubleshooting, and performance monitoring experience and has presented numerous papers around the world. 

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  • The Exceptional Price Performance of Oil - Explanations and Prospects

    Contains 3 Component(s), Includes Credits Recorded On: 10/24/2019

    Presented by Dr. Roberto Aguilera

    Oil price developments over the past 45 years have been truly spectacular. In constant money, prices rose by 759% between 1970-72 and 2012-14. This can be compared with a price index for metals and minerals, which increased by a mere 38%. Analysis shows that the exceptionality of oil’s upward price push over the past decades cannot be adequately explained by cost-raising depletion or by OPEC interventions. The better explanation is an inadequate development of production capacity, caused by above-ground hurdles; e.g. onerous fiscal regimes and conflicts over resource rents. Despite past experience, a turning point has been reached where scarcity, uncertain supply and high prices will be replaced by abundance, undisturbed availability and suppressed price levels. Technical advances in drilling and hydraulic fracturing, which led to fast rising oil and natural gas production in the US but is also applicable to unconventional and conventional formations worldwide, will assure ample and diversified future supply. Although short-run price spikes may occur, oil prices are unlikely to prevail above the total production costs of new supplies, which are estimated to settle at $40-60/barrel in the coming two decades. Expanding global gas output and trade will likely depress gas prices as well. It is concluded that oil and gas will continue to play an important role in satisfying energy demand, from Asia to the Americas, with innovation that will allow for economic production in spite of low prices.

    All content contained within this webinar is copyrighted by Roberto Aguilera and its use and/or reproduction outside the portal requires express permission from Roberto Aguilera.

    Dr. Roberto Aguilera

    Research Fellow, Curtin University Oil and Gas Innovation Centre, Australia

    From 2013-2017, Dr. Aguilera was an analyst with the OPEC Secretariat, Vienna, and a co-author of their annual World Oil Outlook. Previous affiliations include IIASA, University of Vienna, Catholic University of Chile and Servipetrol. He has participated in numerous energy studies, including with the World Petroleum Council and US National Petroleum Council. He holds PhD and Master degrees from Colorado School of Mines and a Bachelor’s from Haskayne School of Business, University of Calgary. His publication record comprises The Price of Oil, a book published by Cambridge University Press (2015) in English and Chinese.

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  • Preparing the Next Generation Workforce for the Digital Transformation of the Oil and Gas Industry – Interview with Angela Dang Atkinson

    Contains 1 Component(s) Recorded On: 10/18/2019

    Tune in to this 30-minute interview to gain insight into this industry expert’s personal views and professional experiences on how leadership challenges are similar yet different, in the world of digital transformation.

    Preparing the next generation workforce for the digital transformation of the Oil & Gas Industry is a critical task. The Big Crew Change of professionals hired in the 1970s and 1980s is largely over with and a new generation is taking their place. Beyond the obvious changes in technology, what other skills will the new petroleum engineer need and what new challenges will they face in the digital oilfield 2.0?

    Tune in to this 30-minute interview to gain insight into this industry expert’s personal views and professional experiences on how leadership challenges are similar yet different, in the world of digital transformation. 

    Interview with: Angela Dang Atkinson, Data Scientist, Cognite

    Interviewed by: Jim Crompton, Reflections Data Consulting / CO School of Mines

    Angela Dang Atkinson

    Data Scientist, Cognite

    Angela earned her B.A. in Biochemistry at Colorado College and her M.Sc. in Petroleum Engineering at the Colorado School of Mines.

    Prior to joining Cognite, Angela served in various roles at Encana Corporation, a North American energy producer with core natural gas and oil assets in the Permian, Eagle Ford, STACK/SCOOP, Montney, and Duvernay plays. She has a wide range of oil and gas experience from onshore field operations to reserves evaluation, predictive data analytics, research experience with Schlumberger Doll Research, and technical data management skills honed at Occidental Petroleum (now California Resource Corporation).

    Angela is the recipient of the 2018 SPE Rocky Mountain Region Young Outstanding Member Award for exceptional service and dedication to the oil and gas community in Denver. She has been a champion of STEM education and women in STEM since her early career, mentoring young women through the Denver Public Schools Career Coach program.

    A believer in the power of liberating data for agile and informed decision making through dashboarding and data analytics, Angela has focused her career on creating fundamental pathways for technical, industrial professionals to more easily access critical information. An adventure-seeker with a penchant for traveling, climbing mountains, cooking, and learning languages, her curiosity often leads her down the less-traveled roads both personally and professionally.

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    Members : Free!

    Non-members : USD 50.00

  • Data Science Project from End to End: A Sucker-Rod Pump Example

    Contains 3 Component(s), Includes Credits

    The concepts behind the digital oilfield will be discussed and how they fit together into creating an ecosystem to deliver value. Concrete elements will be presented that illustrate the entire value chain and technology stack necessary to deliver on the promise of the digital oilfield. We illustrate this vision with a concrete example in which live data from an entire oilfield full of sucker-rod pumps is fed into a central facility, analyzed for predictive maintenance, and used to perform proactive maintenance on the pumps.

    The concepts behind the digital oilfield will be discussed and how they fit together into creating an ecosystem to deliver value. Concrete elements will be presented that illustrate the entire value chain and technology stack necessary to deliver on the promise of the digital oilfield. We illustrate this vision with a concrete example in which live data from an entire oilfield full of sucker-rod pumps is fed into a central facility, analyzed for predictive maintenance, and used to perform proactive maintenance on the pumps. Apart from various physical technologies, we will go into some detail on the analytics used to obtain the result. While the digital oilfield is a large complex made up of many moving parts, the central message of this webinar is that there are two essential factors that govern the success of the entire enterprise: Analytics and change management. Both of these will be discussed and the value of the final outcome will be quantified. Finally, we will present some lessons learned that can be applied to any digital oilfield.

    All content contained within this webinar is copyrighted by Dr. Patrick Bangert and its use and/or reproduction outside the portal requires express permission from Dr. Patrick Bangert.

    Dr. Patrick Bangert

    Founder/CEO, Algorithmica Technologies

    Dr. Bangert is the founder and CEO of Algorithmica Technologies, a machine learning company specializing in oil and gas applications. He was educated as a theoretical physicist and took his PhD in applied mathematics from University College London. After a few research positions at Los Alamos National Laboratory and NASA’s Jet Propulsion Laboratory, Patrick became Assistant Professor of applied mathematics at Jacobs University Bremen in Germany. In 2005, he founded Algorithmica in order to bring the machine learning methods from the ivory tower into real-life practice. He now analyzes empirical data from upstream and downstream plants the world over to provide production optimization and predictive maintenance using machine learning methods. Patrick lives in Cupertino, California.

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