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  • Advanced Imaging and Characterization of Shale rocks – Critical Role in Unconventional Development

    Contains 2 Component(s), 0.15 credits offered Recorded On: 03/20/2018

    Increased activity in unconventional (shale) reservoirs has prompted advances in electron microscope imaging and it has resulted in formulation of protocols for shale reservoir characterization. We will discuss characterization workflows and illustrate results.

    In conventional exploration, shales are important as sealing lithologies and as source rocks. As such, their strength and geochemical properties have been the object of much study. In unconventional exploration, the shale formation acts as source, seal, and reservoir so that we examine shales by focusing on their reservoir properties. In particular, total organic carbon (TOC) and porosity (storage capacity) are important reservoir quality indicators. With that in mind, characterization of the organic matter in these rocks is of prime importance.   

    Characterization workflows start with the imaging of the core using a host of imaging modalities. These include, but are not limited to the following: whole-core (single- and dual-energy) helical computed tomography; micro-CT scans (of 1-in. core plugs obtained from the whole core, selected on the basis of whole-core CT, and ties to well log data); standard sedimentary petrography for characterization of sedimentary structures; organic petrology (reflected and fluorescent light imaging); Raman spectroscopy;  high-resolution, two-dimensional scanning electron microscopy of polished (argon ion milled) samples; three-dimensional scanning electron imaging (using image reconstruction); and transmission electron imaging of organic matter to gain a detailed understanding of the organic matter with respect to storage capacity and morphology. TEM analysis follows the earlier nondestructive techniques/analyses used to characterize the organic matter. Imaging studies are run in parallel with shale rock properties (SRP) measurements made on both intact and crushed material. Imaging and image analysis tied to the physical property measurements allow for the development of predictive rock properties models. 

    Increased activity in unconventional (shale) reservoirs has prompted advances in electron microscope imaging and it has resulted in formulation of protocols for shale reservoir characterization. We will discuss characterization workflows and illustrate results.

    Kultaransingh (Bobby) Hooghan

    Speaker

    Bobby has a Master’s degree in Physics from Mumbai University and one in Engineering Technology from University of North Texas.  He has been doing SEM imaging work since college focusing on FIB/SEM since 1995.  He taught courses in FIB at Microelectronic conferences from 1990 to 2012 and has extensive experience in imaging, including Cryo and Environmental Imaging.  He has contributed to FIB related handbooks and been awarded three (3) US patents for Microelectronic.  For seven years, Bobby worked exclusively on geologic application for Weatherford Labs, where he primarily carried out electron imaging of shales and organic matter characterization using a multitude of techniques and modalities. He has authored several publications in this field and earned one US and one Australian patent for Oil & Gas applications.   

    Lori Hathon

    Assistant Professor of Petroleum Engineering, University of Houston.

    Dr. Hathon received a Bachelor of Science degree, with Honors, from Michigan State University, and a PhD in Sedimentary Petrology from the University of Missouri.  After finishing her education, she spent six years in Exploration and Production with Amoco Production Company, and 20 years in fundamental rock properties research at Shell International E&P, Inc.  Her areas of research include forward modeling of clastic reservoir properties (diagenesis, porosity, permeability), imaging and image analysis linked to rock properties measurements (digital rocks),  and modeling of geomechanical properties (compressibility and strength).  The last several years of her tenure at Shell were devoted to understanding organic matter catagenesis and porosity evolution in shale reservoirs.  

    SPE Webinars are FREE to members courtesy of the

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  • Best Practices to Reduce Venting and Flaring with Economic Benefit

    Contains 2 Component(s), 0.10 credits offered Recorded On: 03/20/2018

    The presentation discusses the drivers for reducing venting and flaring and gives a step by step approach to address EPA Compliance Alert from project identification to ultimate success in sending gas to a gathering or sales pipeline. The characteristics of storage tank vent gas are discussed.

    Existing and evolving regulatory requirements require oil and gas producers to reduce venting and flaring of natural gas from their operations. Regulatory agencies tightening venting and flaring emissions include Environment Canada, the U.S. Environmental Protection Agency’s (USEPA), U.S. Department of the interior, state/province environmental and oil and gas mining regulatory agencies. These rules seek to minimize the loss of natural resources and to reduce air pollution emissions. The air pollutants of concern include volatile organic compounds (VOCs) and the greenhouse gases methane and carbon dioxide. The source of the natural gas is primarily flash gas liberated from the storage of crude oil and condensate. The presentation discusses the drivers for reducing venting and flaring and gives a step by step approach to address  EPA Compliance Alert from project identification to ultimate success in sending gas to a gathering or sales pipeline. The characteristics of storage tank vent gas are discussed. Steps include identifying project scope and emission standards, design data needs, best design practices, installation, commissioning and monitoring systems. The use of smart systems to measure and monitor system operation and the amount of gas recovered is included. Also covered is the design and use of vapor recovery towers (VRTs) to reduce the chance of oxygen entering the vapor recovery systems.  Supplemental emission controls using vapor combustion units as backups to the vapor recovery system is also addressed. The presentation will also introduce new technologies used to automate the detection and reporting of leaks from open thief hatches used on storage tanks, No Heat Acoustic Crude Stabilization and Gas Measurement.

    Jeffrey Voorhis

    Speaker

    Mr. Voorhis obtained the degree of Bachelor of Science in Petroleum and Natural Gas Engineering from Kingsville Texas A & M University in 1983. In January 2012, Mr. Voorhis joined HY-BON ENGINEERING and has been using his oil and gas permit expertise to overcome regulatory barriers  Mr. Voorhis is a registered professional engineer in the State of Texas and has 22 years of private sector engineering experience in the on shore/off shore petroleum industry. He has also served 22 years’ work for the Texas Commission on Environmental Quality, (TCEQ) and Texas Railroad Commission (RRC) where he provided engineering and technical assistance on pollution prevention in the United States and Mexico. In these diverse functions, he has successfully provided technology to many pollution prevention and environmentally conscious projects, resulting in over 250 million dollars a year in savings.. He has many publications including preparation of Texas Pollution Prevention Assessment Manual and Case Studies of Source Reduction and Waste Minimization by Texas Industries. He has served on FOSTTA and many EPA committees. He is also was project leader for TSCA, PPIS, RCRA, Galveston Bay, and NICE3 grants. Mr. Voorhis is also a Registrar Accreditation Board Environmental Management Systems Lead Auditor for ISO 14000. He was the first certified EMS Lead Auditor in state service. Mr. Voorhis was named was TCEQ employee of the Year in Pollution Prevention in 2005.

    SPE Webinars are FREE to members courtesy of the

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  • Implementation of State of the Art Coiled Tubing Technologies in Challenging Completions

    Contains 2 Component(s), 0.15 credits offered Recorded On: 03/13/2018

    Two industry experts will provide insights on new coiled tubing technology applications focused on driving innovation and incremental well performance. This will be a combined webinar presentation that will focus on cost effective abrasive jetting technologies and real time assessment of stimulation fluid diversion by employing coiled tubing fiber optics.

    Two industry experts will provide insights on new coiled tubing technology applications focused on driving innovation and incremental well performance. This will be a combined webinar presentation that will focus on cost effective abrasive jetting technologies and real time assessment of stimulation fluid diversion by employing coiled tubing fiber optics.

    “Abrasive Jetting Applications throughout the Life of a Well-From Drilling to Plug and Abandonment” 

    The use of abrasives mixed in a fluid under pressure has been used in the oilfield for over 50 years.  Abrasive jetting was rediscovered as a perforating method on coiled tubing in the late 1990’s and has demonstrated distinct advantages over traditional explosive perforating.  Today’s abrasive jetting technologies seek to find ways to combine the superior performance and safety into increasingly cost efficient methods to save operators time and money. Applications for abrasive jetting can be found from drilling to production to plug and abandonment, making it extremely versatile. 

    This presentation educates the participant about new applications for abrasive jetting technology throughout the life cycle of the well. Abrasive jetting is no longer just a means for perforating casing - it can be used to help free stuck pipe in drilling; reduce coiled tubing runs for completing new wells; recomplete and stimulate producing wells; evaluate cement bond during plug and abandonment activities; and more.  Technical improvements are also discussed that improve effectiveness of the technology and are demonstrated in case histories. We will also look at what the future holds for this technology and where the next benefits can be found.

    “Overcoming Challenges of Stimulating a Deepwater, Frac Pack Completed Well in the Gulf of Mexico Using Coiled Tubing with Real-Time Downhole Measurements”

    Achieving effective fluid coverage of stimulation operations in deep water frac-pack completions is often  challenging due to a variety of factors, including but not limited to the length of screened intervals, the uncertainty of damage mechanisms, and the ability of diversion materials/fluids to divert beyond the screens and into the formation. This case study demonstrates a successful technique used in conditions not previously attempted.  

    This particular well had two deep high pressure commingled zones.  Previous operations had indicated the presence of a fish or obstruction near the lower portion of the bottom zone.  Several previous attempts to stimulate the well had failed.  This was one of the deepest uses of fiber optic cable ever attempted, and the tools used needed to be tested and rated for operations outside their rated operating envelope.  

    This treatment with fiber optic equipped CT and a rotating, hydraulic high-pressure jetting tool was able to achieve a successful stimulation of a 500 ft long frac packed zone after several previous failures using different techniques.  A 75% increase in production was achieved by using a CT equipped with fiber optics and downhole measurement tools. Engineers were able to perform a data-driven operation based on real-time bottomhole measurements and distributed temperature surveys.

    Thomas Dotson

    President, TD Tools, Inc.

    Mr. Dotson is the President of TD Tools, Inc.  He is a design engineer and inventor with twenty years of experience in pumping services, tool design, research and development, and consulting. He has a Bachelor of Science degree from Western Kentucky University in Physics. Thomas holds eight U.S. patents, has published three papers on sand jet perforating and cutting with the SPE. He founded TD Tools, Inc. in 2007.

    Eric Gagen

    Petroleum Engineer, Schlumberger

    Mr. Gagen has 20 years of experience in the oilfield and a Bachelor’s Degree in Petroleum Engineering from Berkeley.  He has served in a variety of technical and engineering management functions.  With Coil Tubing Services he was involved in organizing and expanding one of the largest independent coiled tubing companies in North America prior to their purchase by Smith.  His primary expertise is in reliably melding developing technologies with existing operations.

    SPE Webinars are FREE to members courtesy of the

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  • First-Ever Environmental Characterization of Hydraulic Fracturing for Shale Oil and Gas Production

    Contains 2 Component(s), 0.15 credits offered Recorded On: 03/08/2018

    Presented by Daniel Tormey

    The well completion process of high volume hydraulic fracturing has become a touchstone for opposition to the development of oil and gas resources from shale source rocks. Although the development of shale gas and oil has brought substantial economic, geopolitical, and climate change benefits to the United States, hydraulic fracturing has displaced global climate change as the most controversial environmental policy issue. As other countries evaluate development of shale oil and gas, these same environmental concerns are available on the internet and media sources. Without data, the concerns become a substantial hindrance to acceptance of shale gas development.

    This study presents the first-ever peer-reviewed study that quantifies the effects of two specific high-volume hydraulic fracturing jobs to 14 different environmental resource categories. The objective was to provide factual information supported by a high-quality dataset to guide policy making. None of the measurements detected a change due to hydraulic fracturing, including microseismic effects, ground motion and induced seismicity, water quality, methane migration, community health, well integrity, fracture containment to the target zone, and others.  

    The hydraulic fracturing occurred in the center of Los Angeles, California, at the largest urban oil field in the US. The level of community and regional concern, the breadth of the study, and many of the results are applicable to other shale oil and gas areas worldwide. The results provide the first dataset that addresses the range of concerns directly, and finds no adverse effects to any of the environmental resource categories. The results have subsequently been used at state and national levels in the United States to further the understanding of these issues.

    Dr. Daniel Tormey

    Energy, Water, and Land Management Expert

    Dr. Tormey is an expert in energy, water, and land management, and he conducts environmental reviews for both government and industry. He works with the environmental aspects of all types of energy development, with an emphasis on oil and gas, including hydraulic fracturing and produced water management, pipelines, LNG terminals, refineries and retail facilities. He has a Ph.D. in Geology and Geochemistry from MIT, and a B.S. in Civil Engineering and Geology from Stanford. He is President of Catalyst Environmental Solutions.  He was named by the National Academy of Sciences to the Science Advisory Board for Giant Sequoia National Monument; is a Distinguished Lecturer for the Society of Petroleum Engineers (SPE); is a member of the International Union for the Conservation of Nature (IUCN) Geoscientist Specialist Group; is on the review committee on behalf of IUCN for the UNESCO World Heritage Site List; is volcanologist for Cruz del Sur, an emergency response and contingency planning organization in Chile; was an Executive in Residence at California Polytechnic University San Luis Obispo; is a Professional Geologist in California; and is a Fellow of The Explorers Club. He has worked throughout the USA, Australia, Indonesia, Italy, Chile, Argentina, Ecuador, Colombia, Venezuela, Brazil, Senegal, South Africa, Armenia and the Republic of Georgia.

    SPE Webinars are FREE to members courtesy of the

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  • Mechanical Integrity Lessons Learned from API Process Safety Site Assessments: Driving Operational Excellence

    Contains 2 Component(s), 0.10 credits offered Recorded On: 03/08/2018

    The API Process Safety Site Assessment Program was developed in 2011.This presentation will provide an overview of the program and present some of the mechanical integrity learnings, trends and benchmarking data developed from the assessments based on the five-year history of the program.

    The API Process Safety Site Assessment Program was developed in 2011 as part of the AFPM and API Advancing Process Safety Programs.  PSSAP began conducting assessments in 2012. By the end of 2017, the API Site Assessment program will have conducted 59 General (7 protocols) and 34 HF Alkylation/RP 751 assessments. These assessments have been conducted 63 different refineries and petrochemical facilities. The areas assessed are: Process Safety Leadership, Management of Change, Mechanical Integrity, Safe Work Practices, Operating Practices, Facility Siting, Process Hazards Analysis, and HF Alkylation/RP 751. Mechanical integrity typically scores 10 percentage points lower than the other areas. This presentation will provide an overview of the program and present some of the mechanical integrity learnings, trends and benchmarking data developed from the assessments based on the five-year history of the program.

    Chad Patschke

    CPSA

    Mr. Patschke has more than 20 years of experience in maintenance; mechanical integrity (MI); process safety management (PSM); and various engineering assignments involving operations, maintenance, process safety, and project management. He has held the positions of plant manager, operations manager, production superintendent, engineering manager, and materials engineer.

    He has both domestic and international experience in a variety of industries that have processes involving highly hazardous chemicals, including refining, oil and gas production (both onshore and offshore), petrochemical, LNG, specialty chemical, pharmaceutical, fertilizer, consumer products, ammonia refrigeration, and hazardous waste treatment operations. He has taught numerous training courses on mechanical integrity and understanding RAGAGEPs, and has written numerous articles on related topics.

    Currently Mr. Patschke assists clients with all aspects of MI as well as PSM program development, implementation, and auditing to satisfy U.S. OSHA’s PSM regulation, U.S. EPA’s RMP rule, U.S. BSEE’s SEMS rule, internal company standards, and good industry practices. He also leads and participates on teams investigating MI-related incidents and provides expert witness services to clients.

    Mr. Patschke is an active member of the API Committee on Refinery Equipment and the Subcommittee on Inspection. He is a Certified Process Safety Auditor (CPSA) and was selected to participate on the joint API/AFPM Process Safety Site Assessment team for conducting site assessments and API RP 751, Safe Operation of HF alkylation unit audits at multiple refineries throughout the U.S. Mr. Patschke previously held inspector certifications for API 510 Pressure Vessels, API 653 Atmospheric Storage Tanks, and API 570 Process Piping, and he has developed and managed MI programs for a variety of companies.

    SPE Webinars are FREE to members courtesy of the

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  • Risk not Chance, STEM Student Risk Awareness

    Contains 1 Component(s)

    These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.​

    The goal of the Risk Not Chance project is to increase risk awareness, and improve the understanding of risk and choice for STEM students. This project aims to increase the understanding of how risk plays a role in our everyday lives, how it can be misunderstood and how we use it to make decisions. These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.

    Thank you to the United Engineering Foundation for supporting the creation of these videos. Without their support, these videos would have never been possible. Please visit https://www.uefoundation.org/ for more information about this project and others.

  • Risk not Chance, First Responders Risk Awareness

    Contains 1 Component(s)

    These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.

    First responders have a unique role and perspective when dealing with safety at industrial sites. While this video is largely aimed at first responders, it’s a great way for chemical engineers to understand their role and perspective when dealing with industrial facilities. Understand what they require and why, and learn how their emergency response plan prioritizes to manage risk for them, the surrounding community, and those at the facility. 

    This video is part of the Risk Not Chance project, which was designed to increase risk awareness, and improve the understanding of risk and choice for first responders. The project aims to increase the understanding of how risk plays a role in our everyday lives, how it can be misunderstood and how we use it to make decisions. These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.

    Thank you to the United Engineering Foundation for supporting the creation of these videos. Without their support, these videos would have never been possible. Please visit https://www.uefoundation.org/ for more information about this project and others.



  • Risk not Chance, Community Risk Awareness

    Contains 1 Component(s)

    These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.

    The goal of the Risk Not Chance project is to increase risk awareness, and improve the understanding of risk and choice for the community. This project aims to increase the understanding of how risk plays a role in our everyday lives, how it can be misunderstood and how we use it to make decisions. These videos help the end user recognize we encounter risk every day, and we mitigate this risk by introducing barriers.

    Thank you to the United Engineering Foundation for supporting the creation of these videos. Without their support, these videos would have never been possible. Please visit https://www.uefoundation.org/ for more information about this project and others.

  • An Improved Well Path Tortuosity Model

    Contains 2 Component(s), 0.15 credits offered Recorded On: 02/28/2018

    Wellbore tortuosity is a critical element in drilling complex horizontal wells and deep verticals. The current three-dimensional borehole trajectory model, based on the minimum curvature method [MCM], tends to mathematically smoothen the wellpath.

    Wellbore tortuosity is a critical element in drilling complex horizontal wells and deep verticals. The current three-dimensional borehole trajectory model, based on the minimum curvature method [MCM], tends to mathematically smoothen the wellpath. This is due to the assumption that the borehole is composed of constant curvature arcs. This assumption creates an artificially low tortuosity expressed as dogleg severity [DLS] which leads to the miscalculation of borehole positions, and generating unreliable prediction of torque and drag. A robust three-dimensional trajectory model, the Advanced Spline-Curve [ASC] model, is developed to overcome these limitations. The ASC model provides realistic results and accurately calculates the spatial course of the wellpath. Various applications of the ASC model are presented including [1] production challenges such as ESP failures and liquid loading, [2] wellbore location affect to reservoir modeling and [3] tortuosity effects on torque and drag, limiting the horizontal distance to be drilled, and raising the question: “how far can you go?”.

    Dr. Mahmoud Abughaban

    Research Scientist, Saudi Aramco

    Dr. Abughaban is a research scientist at the Upstream Research and Development Center – Saudi Aramco. He received his Ph.D. in Petroleum Engineering from Colorado School of Mines. Dr. Abughaban has been actively involved in research projects in the drilling industry. Dr. Abughaban joined Saudi Aramco in 2008 as a Drilling Engineer both onshore and offshore. He has managed critical drilling operations and worked closely with Geologists, Reservoir Engineers and Production engineers to improve rig performance utilizing state of the art technologies and best practices. During his academic period, he has taught undergraduate and graduate courses in Petroleum Engineering. Dr. Abughaban is an active member of the Society of Petroleum Engineering (SPE) and a committee member of SPE-KSA Chapter.

    SPE Webinars are FREE to members courtesy of the

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  • Vertical Multiphase Flow Modeling In Wells And Risers

    Contains 2 Component(s), 0.10 credits offered Recorded On: 02/22/2018

    The aim of the presentation is to show that vertical multiphase flow, which is known to have some very complex features, can be modeled well with 1D methods, using relatively simple assumptions.

    Accurate models for multiphase flows in vertical pipes are needed for the design and operation of hydrocarbon production systems. Examples of important application areas are:

    •       Predicting the time-of-death of gas wells.
    •       Predicting the correct flow rate in liquid-dominated production systems, especially for deep water risers.

    In this presentation we show how vertical multiphase flow can be modeled using a 1D approach. Specifically, we explain what kind of assumptions are needed, and which physical mechanisms require closure laws. Furthermore, we show some recent experimental work conducted at industrial conditions, aimed at deriving more accurate models, and we provide some examples of how the certain closure laws have been deduced from this new data. Finally, we assemble the new closures into a unified model, and compare the predicted pressure drop and liquid content with measured values for a large experimental database on vertical flow. We also test the new model against measurements made in a 3600 meters deep gas well, where we are able to match the measured onset of liquid loading.

    The aim of the presentation is to show that vertical multiphase flow, which is known to have some very complex features, can be modelled well with 1D methods, using relatively simple assumptions.

    Dr. Neeraj Zambare

    LedaFlow Product Director, Kongsberg Digital

    Dr. Zambare has been working with Kongsberg for 17 years now (2001 – current). His field of experience includes flow assurance and process modeling – specifically dynamic simulation related. He led teams to deliver engineering studies, operator training simulators and real-time online modeling on various project around the globe. Dr. Zambare has a MS/PhD in chemical engineering from Drexel Univ., Philadelphia. He is currently responsible for LedaFlow business globally.

    Dr. Jorn Kjolaas

    Senior Scientist, SINTEF Multiphase Flow Laboratory, Tiller

    Dr. Kjolaas has been at the SINTEF Multiphase Flow Laboratory for 16 years. His main fields of experience are experiments and modelling of multiphase flows. He has a PhD from NTNU under Prof. Ole Jørgen Nydal and is the Head of LedaFlow 1D hmodel development.


    SPE Webinars are FREE to members courtesy of the

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