Anthony Kovscek
Keleen and Carlton Beal Professor of Petroleum Engineering
Energy Science & Engineering
Academic Appointments
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Professor, Energy Science & Engineering
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Affiliate, Precourt Institute for Energy
Administrative Appointments
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Chair, Energy Resources Engineering (2012 - 2018)
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Professor of Energy Science & Engineering, Stanford University (2022 - Present)
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Professor of Energy Resources Engineering, Stanford University (2010 - 2022)
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Associate Professor of Energy Resources Engineering, Stanford University (2006 - 2010)
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Associate Professor of Petroleum Engineering, Stanford University (2003 - 2006)
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Assistant Professor of Petroleum Engineering, Stanford University (1996 - 2003)
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Postdoctoral Scholar, Earth Sciences Division, Lawrence Berkeley National Laboratory (1994 - 1996)
Honors & Awards
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Member, U.S. National Academy of Engineering (2023)
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John Franklin Carll Award for Distinguished Contributions to Engineering, Society of Petroleum Engineers (2021)
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Keleen and Carlton Beal Professorship, Stanford University (2015)
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Lester C Uren Award for Distinguished Achievement, Society of Petroleum Engineers (2015)
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Distinguished Member, Society of Petroleum Engineers (2015)
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Distinguished Lecturer. Carbon Sequestration, Global Climate and Energy Project, Stanford University (2008)
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SPE Distinguished Achievement Award for Petroleum Engineering Faculty, Stanford University (2006)
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School of Earth Sciences Award for Excellence in Teaching, Stanford University (1997-1998)
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Tau Beta Pi, Univ. of Washington (1988)
Boards, Advisory Committees, Professional Organizations
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Chair of Energy Resources Engineering, Stanford University (2012 - 2018)
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Breadth Governance Board, Ways of Thinking and Doing, Stanford University (2012 - 2014)
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Codirector of SCCS, Stanford Center for Carbon Storage Affiliates, Stanford University (2011 - Present)
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Chair, Faculty Search Committee Energy Resources Engineering, Stanford University (2011 - 2011)
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Invited Speaker, China University of Petroleum, Beijing China (2011 - 2011)
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Technical Program Committee, SPE Western Regional Meeting, Society of Petroleum Engineers (2011 - 2011)
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Cochair of Steering Committee, SPE Forum, Digital Rocks: Realizing Step Change in the Value of Laboratory Data (2010 - 2011)
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Invited Speaker: Department of Chemical Engineering, University of California at Santa Barbara, et al. (2010 - 2010)
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Technical Program Committee, SPE Western Regional Meeting, Society of Petroleum Engineers (2010 - 2010)
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Invited Speaker, Department of Petroleum and Geosystems Engineering, University of Texas and Chemical Engineering and Materials Science, University of Southern California (2009 - 2009)
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Executive Editor, SPE Journal, Society of Petroleum Engineers (2009 - 2012)
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Associate Chairman, Energy Resources Engineering, Stanford University (2008 - 2011)
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Chair, Faculty Search Committee, Energy Resources Engineering, Stanford University (2008 - 2008)
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Marshall, 117th Commencement June 15, Stanford University (2008 - 2008)
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Technical Program Committee, SPE Western Regional Meeting, Society of Petroleum Engineers (2008 - 2009)
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Organizing Committee, SPE Forum, Maximizing Oil Recovery in the 21st Century, Colorado Springs, CO., Society of Petroleum Engineers (2008 - 2009)
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Society of Petroleum Engineers, Books Development Committee, Society of Petroleum Engineers (2008 - 2009)
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Technical Program Committee, SPE Western Regional Meeting, Society of Petroleum Engineers (2007 - 2008)
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Member, Faculty Search Committee, Energy Resources Engineering, Stanford University (2007 - 2007)
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SPE Publications Coordinating Committee, Society of Petroleum Engineers (2007 - 2008)
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Steering Committee, 6th Annual Conference on Carbon Capture and Sequestration, Pittsburg, PA, Conference on Carbon Capture and Sequestration (2007 - 2007)
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Editorial Board, SPE Reservoir Evalulation & Engineering, Society of Petroleum Engineers (2006 - 2009)
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Member, American Geophysical Union (AGU), American Geophysical Union (2006 - Present)
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Member, Energy Committee, Woods Institute for the Environment at Stanford University (2005 - Present)
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Chair, Energy Resources Engineering Admissions Committee, Stanford University (2005 - Present)
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Chair of Steering Committee, SPE Forum, Enhanced Oil Recovery: What's Next?, Society of Petroleum Engineers (2005 - 2006)
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Invited Speaker, BP Anchorage, AK, and ExxonMobil Research and Engineering Co. Clinton, NJ (2005 - 2005)
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Steering Committee Member, 4th Annual Conference on Carbon Capture and Sequestration, Alexandria, VA, Conference on Carbon Capture and Sequestration (2005 - 2005)
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SPE Western Regional Meeting Program Committee and Session Chair, Society of Petroleum Engineers (2005 - 2005)
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Freshman Advisor, Stanford University (2004 - 2008)
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Marshall, 113th Commencement, June 13, Stanford University (2004 - 2004)
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Invited Speaker: Petroleum Technology Transfer Council, SPE Advanced Technology Workshop on Reservoir Physics, Gordon Reseach Conference--Flow and Transport in Permeable Media, Society of Petroleum Engineers (2004 - 2004)
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Journal of Petroleum Technology, Editorial Committee, Journal of Petroleum Technology (2004 - Present)
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Chair, SPE Continuing Education Committee, Society of Petroleum Engineers (2004 - 2005)
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Invited Speaker: Department of Chemical Engineering, University of California, Berkeley,, University of California, Berkeley, PetroChina, Beijing China, Aera Energy LLC, Bakersfield, CA (2003 - 2003)
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Organizer, ACS Award in Colloid Chemistry Symposium Honoring Clayton J. Radke, American Chemical Society (2003 - 2003)
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Editor of a Special Issue of the Journal of Petroleum Science and Engineering honoring Professor W. E. Brigham, Journal of Petroleum Science and Engineering (2003 - 2003)
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Member, Faculty Search Committee, Petroleum Engineering, Stanford University (2002 - 2003)
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Invited Speaker: Department of Civil Engineering, University of California, Berkeley, Huainan Institute of Technology, Anhui China, University of California, Berkeley and Huainan Institute of Technology, Anhui China (2002 - 2002)
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Session Chairman: SPE/DOE Improved Oil Recovery Symposium, Society of Petroleum Engineers and Department of Energy (2002 - 2002)
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Invited Speaker, Petroleum Technology Transfer Council (2001 - 2001)
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Invited Panelist, DOE Multiscale Reservoir Investigation Symposium, Organizer SPE Western Region Student Paper Contest, Department of Energy and Society of Petroleum Engineers (2001 - 2001)
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Faculty Search Committee, Geological and Environmental Sciences, Stanford University (2000 - 2000)
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Member, Earth Systems Advisory Committee, Stanford University (2000 - Present)
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Invited Speaker, Chevron Petroleum Technology Co. (2000 - 2000)
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Technical Editor, SPE Reservoir Engineering and Evaluation (2000 - 2006)
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Member, Continuing Education Committee, SPE, Society of Petroleum Engineers (2000 - Present)
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Technical Program Committee/Session Chairman: SPE/DOE Improved Oil Recovery Symposium, SPE Western Regional Meeting, Society of Petroleum Engineers and Department of Energy (2000 - 2000)
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Instructor, Stanford Science and Engineering Academy (1999 - 1999)
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Speaker, The President's Fund Dinner, Stanford University (1999 - 1999)
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Faculty Advisor, SPE student chapter, Stanford University (1998 - Present)
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Member, Petroleum Engineering Department Admissions Committee, Stanford University (1998 - 2002)
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Invited speaker, Mobil Technology Company, Imperial Oil Resources (1998 - 1998)
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Session Chairman: SPE/DOE 11th Symposium on Improved Oil Recovery, 7th UNITAR Conference on Heavy Crude Oil, Society of Petroleum Engineers and Department of Energy (1998 - 1998)
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Freshman and Sophomore advisor, Stanford University (1997 - 2003)
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Organizing Committee: Stanford and Heriot Watt University Forum on Reservoir Description and Modeling, Stanford University and Heriot Watt University (1997 - 1997)
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Member, American Chemical Society (1997 - Present)
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Chairman, Petroleum Engineering Department Safety Committee, Stanford University (1996 - 2008)
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Member, School of Earth Sciences Faculty Library Committee, Stanford University (1996 - Present)
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Member, Society of Petroleum Engineers (1994 - Present)
Professional Education
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Ph.D., Univ. of California, BerkeleyChemical Engineering (1994)
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B.S., Univ. of Washington, Chemical Engineering (1989)
Current Research and Scholarly Interests
Research
Together with my research group, I develop and apply advanced imaging techniques, experimentation, and models to understand complex multiphase flows of gas, water, and organic phases in natural and manufactured porous media with applications in carbon storage, increased utilization of carbon dioxide for subsurface applications, hydrogen storage, and water reuse. In all of our work, physical observations, obtained mainly from laboratory and field measurements, are interwoven with theory.
Teaching
My teaching interests center broadly around education of students to meet the energy challenges that we will face this century. I teach undergraduate courses that examine the interplay of energy use and environmental issues including renewable energy resources and sustainability. At the graduate level, I offer classes on renewable energy processes based on heat and the thermodynamics of hydrocarbon mixtures.
Professional Activities
Member, American Geophysical Union, Society of Petroleum Engineers, and the American Chemical Society.
2024-25 Courses
- Busting Energy Myths
ENERGY 30N (Aut) - ESE Master's Graduate Seminar
ENERGY 351 (Spr) - ESE PhD Graduate Seminar
ENERGY 352 (Spr) - Fundamentals of Energy Processes
EE 293B, ENERGY 201B (Win) - Fundamentals of Renewable Power
EARTHSYS 102, ENERGY 102 (Spr) - Senior Project and Seminar in Energy Science and Engineering
ENERGY 199 (Spr) -
Independent Studies (15)
- Advanced Research Work in Energy Science and Engineering
ENERGY 360 (Aut, Win, Spr) - Directed Individual Study in Earth Systems
EARTHSYS 297 (Aut, Win, Spr) - Directed Reading in Environment and Resources
ENVRES 398 (Aut, Win, Spr) - Directed Research
EARTHSYS 250 (Aut, Win, Spr) - Directed Research in Environment and Resources
ENVRES 399 (Aut, Win, Spr) - Doctoral Degree Research in Energy Science and Engineering
ENERGY 363 (Aut, Win, Spr) - Doctoral Degree Teaching Requirement
ENERGY 358 (Aut, Win, Spr) - Engineer's Degree Research in Energy Science and Engineering
ENERGY 362 (Aut, Win, Spr) - Honors Program in Earth Systems
EARTHSYS 199 (Aut, Win, Spr) - Master's Degree Research in Energy Science and Engineering
ENERGY 361 (Aut, Win, Spr) - Special Research Topics in Energy Science and Engineering
ENERGY 365 (Aut, Win, Spr) - Special Topics in Energy Science and Engineering
ENERGY 273 (Aut, Win, Spr) - Undergraduate Report on Energy Industry Training
ENERGY 155 (Aut, Win, Spr) - Undergraduate Research Problems
ENERGY 193 (Aut, Win, Spr) - Undergraduate Teaching Experience
ENERGY 192 (Aut, Win, Spr)
- Advanced Research Work in Energy Science and Engineering
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Prior Year Courses
2023-24 Courses
- Busting Energy Myths
ENERGY 30N (Aut) - Fundamentals of Energy Processes
EE 293B, ENERGY 201B (Win) - Fundamentals of Renewable Power
EARTHSYS 102, ENERGY 102 (Spr) - Senior Project and Seminar in Energy Science and Engineering
ENERGY 199 (Spr) - Thermodynamics of Equilibria
ENERGY 251 (Aut)
2022-23 Courses
- Busting Energy Myths
ENERGY 30N (Win) - ERE Master's Graduate Seminar
ENERGY 351 (Spr) - ERE PhD Graduate Seminar
ENERGY 352 (Spr) - Fundamentals of Energy Processes
EE 293B, ENERGY 293B (Win) - Fundamentals of Renewable Power
EARTHSYS 102, ENERGY 102 (Spr) - Senior Project and Seminar in Energy Resources
ENERGY 199 (Spr)
2021-22 Courses
- Busting Energy Myths
ENERGY 30N (Aut) - ERE Master's Graduate Seminar
ENERGY 351 (Win) - ERE PhD Graduate Seminar
ENERGY 352 (Win) - Fundamentals of Energy Processes
EE 293B, ENERGY 293B (Win) - Fundamentals of Renewable Power
EARTHSYS 102, ENERGY 102 (Spr) - Senior Project and Seminar in Energy Resources
ENERGY 199 (Spr) - Thermodynamics of Equilibria
ENERGY 251 (Aut)
- Busting Energy Myths
Stanford Advisees
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Doctoral Dissertation Reader (AC)
Priyanka Muhunthan -
Postdoctoral Faculty Sponsor
Laura Froute, Arash Kamali Asl -
Doctoral Dissertation Advisor (AC)
Yulman Perez Claro -
Master's Program Advisor
Isabela Beine, Jeff Edsall, Zitong Huang, Warisa Nuntaprayoon, Siradon Prateepswangwong, Oluwatobi Raji, Asia Zhang -
Doctoral (Program)
Catherine Callas, Emma Li, Lisa Li, Geo Zhang, Jimin Zhou
All Publications
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Scale translation yields insights into gas adsorption under nanoconfinement
PHYSICS OF FLUIDS
2024; 36 (7)
View details for DOI 10.1063/5.0212423
View details for Web of Science ID 001271335900004
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Criteria and workflow for selecting saline formations for carbon storage
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
2024; 135
View details for DOI 10.1016/j.ijggc.2024.104138
View details for Web of Science ID 001296471500001
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The 11th Society of Petroleum Engineers Comparative Solution Project Problem Definition
SPE JOURNAL
2024; 29 (5): 2507-2524
View details for Web of Science ID 001239664700001
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Molecular Assessment of Storage Capacity and Enthalpy of Adsorption in Organic-Rich Shale Gas Reservoirs
ARABIAN JOURNAL FOR SCIENCE AND ENGINEERING
2024
View details for DOI 10.1007/s13369-024-08889-8
View details for Web of Science ID 001190501900003
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A Methodology for Fueling Mobility Markets with Hydrogen from Natural Gas plus Carbon Capture and Sequestration
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
2024; 133
View details for DOI 10.1016/j.ijggc.2024.104095
View details for Web of Science ID 001188214200001
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In Situ pH Measurement in Microfluidic Porous Media Indicated by Surfaces Functionalized with Polyaniline (PAni)
COLLOIDS AND INTERFACES
2024; 8 (1)
View details for DOI 10.3390/colloids8010009
View details for Web of Science ID 001172074400001
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Scaling Up FluidFlower Results for Carbon Dioxide Storage in Geological Media
TRANSPORT IN POROUS MEDIA
2024
View details for DOI 10.1007/s11242-023-02046-9
View details for Web of Science ID 001140996800001
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Coupled Transport, Reactivity, and Mechanics in Fractured Shale Caprocks
WATER RESOURCES RESEARCH
2024; 60 (1)
View details for DOI 10.1029/2023WR035482
View details for Web of Science ID 001144200500001
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Induced Seismicity Hazard Assessment for a Potential CO<sub>2</sub> Storage Site in the Southern San Joaquin Basin, CA
GEOHAZARDS
2023; 4 (4): 421-436
View details for DOI 10.3390/geohazards4040024
View details for Web of Science ID 001187541100001
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Evaluation of Electron Tomography Capabilities for Shale Imaging.
Microscopy and microanalysis : the official journal of Microscopy Society of America, Microbeam Analysis Society, Microscopical Society of Canada
2023
Abstract
Despite the advantageous resolution of electron tomography (ET), reconstruction of three-dimensional (3D) images from multiple two-dimensional (2D) projections presents several challenges, including small signal-to-noise ratios, and a limited projection range. This study evaluates the capabilities of ET for thin sections of shale, a complex nanoporous medium. A numerical phantom with 1.24 nm pixel size is constructed based on the tomographic reconstruction of a Barnett shale. A dataset of 2D projection images is numerically generated from the 3D phantom and studied over a range of conditions. First, common reconstruction techniques are used to reconstruct the shale structure. The reconstruction uncertainty is quantified by comparing overall values of storage and transport metrics, as well as the misclassification of pore voxels compared to the phantom. We then select the most robust reconstruction technique and we vary the acquisition conditions to quantify the effect of artifacts. We find a strong agreement for large pores over the different acquisition workflows, while a wider variability exists for nanometer-scale features. The limited projection range and reconstruction are identified as the main experimental bottlenecks, thereby suggesting that sample thinning, advanced holders, and advanced reconstruction algorithms offer opportunities for improvement.
View details for DOI 10.1093/micmic/ozad106
View details for PubMedID 37942573
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Assessing the impact of dip angle on carbon storage in saline reservoirs to aid site selection
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
2023; 129
View details for DOI 10.1016/j.ijggc.2023.103966
View details for Web of Science ID 001106663500001
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Core-scale numerical simulation and comparison of breakdown of shale and resulting fractures using sc-CO2 and water as injectants
GAS SCIENCE AND ENGINEERING
2023; 118
View details for DOI 10.1016/j.jgsce.2023.205109
View details for Web of Science ID 001165447500001
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Assessing the impact of dip angle on carbon storage in saline reservoirs to aid site selection
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
2023; 129
View details for Web of Science ID 001106663500002
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Intercomparison of numerical simulation models for hydrogen storage in porous media using different codes
ENERGY CONVERSION AND MANAGEMENT
2023; 292
View details for DOI 10.1016/j.enconman.2023.117409
View details for Web of Science ID 001054997100001
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Scoring, ranking, and technoeconomics of carbon capture and storage opportunities in the central valley of California
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
2023; 128
View details for DOI 10.1016/j.ijggc.2023.103968
View details for Web of Science ID 001086235700001
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Analysis of gas storage and transport in Eagle Ford shale using pressure pulse decay measurements with He, Kr and CO2
GEOENERGY SCIENCE AND ENGINEERING
2023; 228
View details for DOI 10.1016/j.geoen.2023.211951
View details for Web of Science ID 001059688600001
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Micro X-ray fluorescence reveals pore space details and spatially-resolved porosity of rock-based microfluidic devices.
Lab on a chip
2023
Abstract
Characterization of microscopic details of the fabric of mudstones and shales (i.e., structure and composition) is important to understand their storage and transport properties. Current characterization methods struggle to probe reliably multiple scales of interest (e.g., pore and fracture) and measure properties at the finest resolution under representative in situ conditions. Micro X-ray fluorescence (muXRF) is a high-performance imaging technique that produces elemental images at sub-10 mum spatial resolution and could offer insight into a diversity of shale properties, such as mineral composition, porosity, and in situ pressure gradients. This study designed and carried out a porosity mapping protocol using model and real-rock microfluidic devices and contrast fluids. Etched silicon micromodels with real-rock pore network patterns served as ideal models to establish a proof of concept. Measurements were performed on a novel muXRF microscope not powered by synchrotron radiation. We registered the muXRF datasets with the binary rock masks used for micromodel fabrication and applied segmentation algorithms to compare porosities. We assessed expected advantages and limitations through a sensitivity analysis and beam study. muXRF is an important new imaging technique for microfluidic applications.
View details for DOI 10.1039/d3lc00394a
View details for PubMedID 37591813
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Environmental impact of solution pH on the formation and migration of iron colloids in deep subsurface energy systems.
The Science of the total environment
2023: 166409
Abstract
Deep subsurface stimulation processes often promote fluid-rock interactions that can lead to the formation of small colloidal particles that are suspected to migrate through the rock matrix, partially or fully clog pores and microfractures, and promote the mobilization of contaminants. Thus, the goal of this work is to understand the geochemical changes of the host rock in response to reservoir stimulation that promote the formation and migration of colloids. Two different carbonate-rich shales were exposed to different solution pHs (pH = 2 and 7). Iron and other mineral transformations at the shale-fluid interface were first characterized by synchrotron-based XRF mapping. Then, colloids that were able to migrate from the shale into the bulk fluid were characterized by synchrotron-based extended X-ray absorption structure (EXAFS), scanning electron microscopy (SEM), and single-particle inductively coupled plasma time-of-flight mass spectrometry (sp-icpTOF-MS). When exposed to the pH = 2 solution, extensive mineral dissolution and secondary precipitation was observed; iron-(oxyhydr)oxide colloids colocated with silicates were observed by SEM at the fluid-shale interfaces, and the mobilization of chromium and nickel with these iron colloids into the bulk fluid was detected by sp-icpTOF-MS. Iron EXAFS spectra of the solution at the shale-fluid interface suggests the rapid (within minutes) formation of ferrihydrite-like nanoparticles. Thus, we demonstrate that the pH neutralization promotes the mobilization of existing silicate minerals and the rapid formation of new iron colloids. These Fe colloids have the potential to migrate through the shale matrix and mobilize other heavy metals (such as Cr and Ni, in this study) and impacting groundwater quality, as well produced waters from these hydraulic fracturing operations.
View details for DOI 10.1016/j.scitotenv.2023.166409
View details for PubMedID 37597537
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Quantification of the Impact of Acidified Brine on Fracture-Matrix Transport in a Naturally Fractured Shale Using in Situ Imaging and Modeling
ENERGY & FUELS
2023
View details for DOI 10.1021/acs.energyfuels.3c01463
View details for Web of Science ID 001040507200001
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Flow characteristics and regime transition of aqueous foams in porous media over a wide range of quality, velocity, and surfactant concentration
PETROLEUM SCIENCE
2023; 20 (2): 1044-1052
View details for DOI 10.1016/j.petsci.2022.11.014
View details for Web of Science ID 000994772700001
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Comparative Analysis of Imaging and Measurements of Micrometer-Scale Fracture Aperture Fields Within a Heterogeneous Rock Using PET and X-ray CT
TRANSPORT IN POROUS MEDIA
2023
View details for DOI 10.1007/s11242-023-01922-8
View details for Web of Science ID 000943631800001
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Pore-scale study of microbial hydrogen consumption and wettability alteration during underground hydrogen storage
FRONTIERS IN ENERGY RESEARCH
2023; 11
View details for DOI 10.3389/fenrg.2023.1124621
View details for Web of Science ID 000935958400001
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The motion of long bubbles in microchannels using a meter-long, rectangular capillary on a chip.
Journal of colloid and interface science
2023; 638: 149-160
Abstract
HYPOTHESIS: The dynamics of gas-liquid interfaces differs between aqueous surfactant and nanoparticle mixtures in rectangular cross-section capillaries.EXPERIMENTS: We designed and fabricated a new microfluidic device with a meter-long channel and a noncircular cross section (35mum by 100mum by 1 m) to study the flow behavior of long bubbles in capillaries wetted by water as well as surfactant and nanoparticle solutions. Flow in the novel symmetric loop device maintains essentially straight and inertialess conditions over a wide range of flow rates.FINDINGS: The pressure-drop versus velocity relationship of long bubbles in capillaries with noncircular cross sections has been studied theoretically but not extensively validated. The measured pressure drop (normalized with respect to interfacial properties) experienced by bubbles varies as Ca2/3 over the range 10-7
View details for DOI 10.1016/j.jcis.2023.01.073
View details for PubMedID 36736116
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Multimodal study of the impact of stimulation pH on shale pore structure, with an emphasis on organics behavior in alkaline environments
FUEL
2023; 331
View details for DOI 10.1016/j.fuel.2022.125649
View details for Web of Science ID 000859556900003
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Mixed imbibition controls the advance of wetting fluid in multiscale geological media
Advances in Water Resources
2023
View details for DOI 10.1016/j.advwatres.2023.104429
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Effects of Supercritical CO2 Injection on the Shale Pore Structures and Mass Transport Rates
ENERGY & FUELS
2022
View details for DOI 10.1021/acs.energyfuels.2c02254
View details for Web of Science ID 000906441200001
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Dynamic development of geochemical reaction fronts during hydraulic stimulation of shale
APPLIED GEOCHEMISTRY
2023; 148
View details for DOI 10.1016/j.apgeochem.2022.105542
View details for Web of Science ID 000913925600001
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Criteria and workflow for selecting depleted hydrocarbon reservoirs for carbon storage
APPLIED ENERGY
2022; 324
View details for DOI 10.1016/j.apenergy.2022.119668
View details for Web of Science ID 000841967400010
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Toward underground hydrogen storage in porous media: Reservoir engineering insights
INTERNATIONAL JOURNAL OF HYDROGEN ENERGY
2022; 47 (79): 33781-33802
View details for DOI 10.1016/j.ijhydene.2022.07.239
View details for Web of Science ID 000865018500004
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Pore level foam generation in the presence of residual oil in porous media
FUEL
2022; 324
View details for DOI 10.1016/j.fuel.2022.124568
View details for Web of Science ID 000809897800007
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A micro-scale rheometer to study foam texture and flow resistance in planar fractures.
Lab on a chip
2022
Abstract
We designed and fabricated a new microfluidic device to better enable study of foam microstructure and rheology in planar fractures. The design phase included stress-strain finite element analysis to enhance the pressure tolerance of the device. The optimized design is a 2 cm wide by 7.75 cm long rough fracture that includes 25 posts to anchor the glass cover plate. The posts simulate asperities and provide structural support during bonding of a glass cover plate to the device. Importantly, the new design illustrates improved ability to sustain large differential pressure compared to previous designs in the literature. The rheometer permits study of the relationship among foam bubble morphology, pressure drop, and flow rates. Our findings validated the previous, sparse microvisual studies mentioned in the literature and confirmed that small quality foam, ranging from 20 to 50% gas by volume, contains dispersed bubbles separated by liquid lenses. In this range, the distribution of bubble sizes was roughly 80-90% small uniform bubbles and only 10-20% of larger and more elongated bubbles. Additionally, our studies reveal that foam apparent viscosity is a strong function of foam quality, velocity, and texture (i.e., bubble size). Apparent viscosity of foam ranged from 100 to 600 cP for the conditions studied. High quality foams in fractures are independent of gas flow rates but very sensitive to liquid flow rates. On the other hand, low quality foams are sensitive to gas flow rates but independent of liquid flow rates.
View details for DOI 10.1039/d2lc00595f
View details for PubMedID 35959658
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Probing multiscale dissolution dynamics in natural rocks through microfluidics and compositional analysis.
Proceedings of the National Academy of Sciences of the United States of America
2022; 119 (32): e2122520119
Abstract
Mineral dissolution significantly impacts many geological systems. Carbon released by diagenesis, carbon sequestration, and acid injection are examples where geochemical reactions, fluid flow, and solute transport are strongly coupled. The complexity in these systems involves interplay between various mechanisms that operate at timescales ranging from microseconds to years. Current experimental techniques characterize dissolution processes using static images that are acquired with long measurement times and/or low spatial resolution. These limitations prevent direct observation of how dissolution reactions progress within an intact rock with spatially heterogeneous mineralogy and morphology. We utilize microfluidic cells embedded with thin rock samples to visualize dissolution with significant temporal resolution (100 ms) in a large observation window (3 × 3 mm). We injected acidic fluid into eight shale samples ranging from 8 to 86 wt % carbonate. The pre- and postreaction microstructures are characterized at the scale of pores (0.1 to 1 µm) and fractures (1 to 1,000 µm). We observe that nonreactive particle exposure, fracture morphology, and loss of rock strength are strongly dependent on both the relative volume of reactive grains and their distribution. Time-resolved images of the rock unveil the spatiotemporal dynamics of dissolution, including two-phase flow effects in real time and illustrate the changes in the fracture interface across the range of compositions. Moreover, the dynamical data provide an approach for characterizing reactivity parameters of natural heterogeneous samples when porous media effects are not negligible. The platform and workflow provide real-time characterization of geochemical reactions and inform various subsurface engineering processes.
View details for DOI 10.1073/pnas.2122520119
View details for PubMedID 35921438
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Long-term permeability evolution of shale seal rocks with argon and scCO(2)
JOURNAL OF NATURAL GAS SCIENCE AND ENGINEERING
2022; 104
View details for DOI 10.1016/j.jngse.2022.104642
View details for Web of Science ID 000822680800002
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Optimization and uncertainty quantification of in situ combustion chemical reaction models
FUEL
2022; 319
View details for DOI 10.1016/j.fuel.2022.123683
View details for Web of Science ID 000783213900008
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Chemical and Reactive Transport Processes Associated with Hydraulic Fracturing of Unconventional Oil/Gas Shales.
Chemical reviews
2022
Abstract
Hydraulic fracturing of unconventional oil/gas shales has changed the energy landscape of the U.S. Recovery of hydrocarbons from tight, hydraulically fractured shales is a highly inefficient process, with estimated recoveries of <25% for natural gas and <5% for oil. This review focuses on the complex chemical interactions of additives in hydraulic fracturing fluid (HFF) with minerals and organic matter in oil/gas shales. These interactions are intended to increase hydrocarbon recovery by increasing porosities and permeabilities of tight shales. However, fluid-shale interactions result in the dissolution of shale minerals and the release and transport of chemical components. They also result in mineral precipitation in the shale matrix, which can reduce permeability, porosity, and hydrocarbon recovery. Competition between mineral dissolution and mineral precipitation processes influences the amounts of oil and gas recovered. We review the temporal/spatial origins and distribution of unconventional oil/gas shales from mudstones and shales, followed by discussion of their global and U.S. distributions and compositional differences from different U.S. sedimentary basins. We discuss the major types of chemical additives in HFF with their intended purposes, including drilling muds. Fracture distribution, porosity, permeability, and the identity and molecular-level speciation of minerals and organic matter in oil/gas shales throughout the hydraulic fracturing process are discussed. Also discussed are analysis methods used in characterizing oil/gas shales before and after hydraulic fracturing, including permeametry and porosimetry measurements, X-ray diffraction/Rietveld refinement, X-ray computed tomography, scanning/transmission electron microscopy, and laboratory- and synchrotron-based imaging/spectroscopic methods. Reactive transport and spatial scaling are discussed in some detail in order to relate fundamental molecular-scale processes to fluid transport. Our review concludes with a discussion of potential environmental impacts of hydraulic fracturing and important knowledge gaps that must be bridged to achieve improved mechanistic understanding of fluid transport in oil/gas shales.
View details for DOI 10.1021/acs.chemrev.1c00504
View details for PubMedID 35404590
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Mechanistic modeling and measurement of foamed gas flow resistance in fractures
ADVANCES IN WATER RESOURCES
2022; 162
View details for DOI 10.1016/j.advwatres.2022.104154
View details for Web of Science ID 000788071600005
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Analysis and comparison of in-situ combustion chemical reaction models
FUEL
2022; 311
View details for DOI 10.1016/j.fuel.2021.122599
View details for Web of Science ID 000743152800002
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Assessment of oil and gas fields in California as potential CO2 storage sites
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
2022; 114
View details for DOI 10.1016/j.ijggc.2022.103579
View details for Web of Science ID 000776040000001
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Fractal Characterization of Multimodal, Multiscale Images of Shale Rock Fracture Networks
ENERGIES
2022; 15 (3)
View details for DOI 10.3390/en15031012
View details for Web of Science ID 000757211600001
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Pore-scale bubble population dynamics of CO2-foam at reservoir pressure
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
2022; 114
View details for DOI 10.1016/j.ijggc.2022.103607
View details for Web of Science ID 000777546100003
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Striving to translate shale physics across ten orders of magnitude: What have we learned?
EARTH-SCIENCE REVIEWS
2021; 223
View details for DOI 10.1016/j.earscirev.2021.103848
View details for Web of Science ID 000721681900001
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Reconstructing porous media using generative flow networks
COMPUTERS & GEOSCIENCES
2021; 156
View details for DOI 10.1016/j.cageo.2021.104905
View details for Web of Science ID 000693555300006
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2D-to-3D image translation of complex nanoporous volumes using generative networks.
Scientific reports
2021; 11 (1): 20768
Abstract
Image-based characterization offers a powerful approach to studying geological porous media at the nanoscale and images are critical to understanding reactive transport mechanisms in reservoirs relevant to energy and sustainability technologies such as carbon sequestration, subsurface hydrogen storage, and natural gas recovery. Nanoimaging presents a trade off, however, between higher-contrast sample-destructive and lower-contrast sample-preserving imaging modalities. Furthermore, high-contrast imaging modalities often acquire only 2D images, while 3D volumes are needed to characterize fully a source rock sample. In this work, we present deep learning image translation models to predict high-contrast focused ion beam-scanning electron microscopy (FIB-SEM) image volumes from transmission X-ray microscopy (TXM) images when only 2D paired training data is available. We introduce a regularization method for improving 3D volume generation from 2D-to-2D deep learning image models and apply this approach to translate 3D TXM volumes to FIB-SEM fidelity. We then segment a predicted FIB-SEM volume into a flow simulation domain and calculate the sample apparent permeability using a lattice Boltzmann method (LBM) technique. Results show that our image translation approach produces simulation domains suitable for flow visualization and allows for accurate characterization of petrophysical properties from non-destructive imaging data.
View details for DOI 10.1038/s41598-021-00080-5
View details for PubMedID 34675247
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Pore-merging methodology for reactive transport and mineral dissolution in pore-network models
ADVANCES IN WATER RESOURCES
2021; 155
View details for DOI 10.1016/j.advwatres.2021.104014
View details for Web of Science ID 000698509000003
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In-Situ Combustion Frontal Stability Analysis
SPE JOURNAL
2021; 26 (4): 2271-2286
View details for DOI 10.2118/195318-PA
View details for Web of Science ID 000700523200037
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Multiphysics Investigation of Geochemical Alterations in Marcellus Shale Using Reactive Core-Floods
ENERGY & FUELS
2021; 35 (13): 10733-10745
View details for DOI 10.1021/acs.energyfuels.1c00588
View details for Web of Science ID 000670646600031
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Multimodal Visualization of Vaca Muerta Shale Fabric Before and After Maturation
ENERGY & FUELS
2021; 35 (11): 9550-9560
View details for DOI 10.1021/acs.energyfuels.1c00037
View details for Web of Science ID 000661109900034
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Mechanistic foam flow model with variable flowing foam fraction and its implementation using automatic differentiation
ADVANCES IN WATER RESOURCES
2021; 150
View details for DOI 10.1016/j.advwatres.2021.103877
View details for Web of Science ID 000634108200006
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Phase-field modeling of rate-dependent fluid-driven fracture initiation and propagation
INTERNATIONAL JOURNAL FOR NUMERICAL AND ANALYTICAL METHODS IN GEOMECHANICS
2021
View details for DOI 10.1002/nag.3190
View details for Web of Science ID 000613319800001
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A Critical Review of the Physicochemical Impacts of Water Chemistry on Shale in Hydraulic Fracturing Systems.
Environmental science & technology
2021
Abstract
Hydraulic fracturing of unconventional hydrocarbon resources involves the sequential injection of a high-pressure, particle-laden fluid with varying pH's to make commercial production viable in low permeability rocks. This process both requires and produces extraordinary volumes of water. The water used for hydraulic fracturing is typically fresh, whereas "flowback" water is typically saline with a variety of additives which complicate safe disposal. As production operations continue to expand, there is an increasing interest in treating and reusing this high-salinity produced water for further fracturing. Here we review the relevant transport and geochemical properties of shales, and critically analyze the impact of water chemistry (including produced water) on these properties. We discuss five major geochemical mechanisms that are prominently involved in the temporal and spatial evolution of fractures during the stimulation and production phase: shale softening, mineral dissolution, mineral precipitation, fines migration, and wettability alteration. A higher salinity fluid creates both benefits and complications in controlling these mechanisms. For example, higher salinity fluid inhibits clay dispersion, but simultaneously requires more additives to achieve appropriate viscosity for proppant emplacement. In total this review highlights the nuances of enhanced hydrogeochemical shale stimulation in relation to the choice of fracturing fluid chemistry.
View details for DOI 10.1021/acs.est.0c04901
View details for PubMedID 33428391
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Multiscale study of CO2 impact on fluid transport and carbonate dissolution in Utica and Eagle Ford shale
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2020; 195
View details for DOI 10.1016/j.petrol.2020.107867
View details for Web of Science ID 000586002900181
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Three-Dimensional Imaging and Quantification of Gas Storativity in Nanoporous Media via X-rays Computed Tomography
ENERGIES
2020; 13 (23)
View details for DOI 10.3390/en13236199
View details for Web of Science ID 000597083800001
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Transport Simulations on Scanning Transmission Electron Microscope Images of Nanoporous Shale
ENERGIES
2020; 13 (24)
View details for DOI 10.3390/en13246665
View details for Web of Science ID 000602826900001
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RockFlow: Fast Generation of Synthetic Source Rock Images Using Generative Flow Models
ENERGIES
2020; 13 (24)
View details for DOI 10.3390/en13246571
View details for Web of Science ID 000602817200001
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Multimodal imaging and machine learning to enhance microscope images of shale
COMPUTERS & GEOSCIENCES
2020; 145
View details for DOI 10.1016/j.cageo.2020.104593
View details for Web of Science ID 000587352100006
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A Critical Review of the Role of Thin Liquid Films for Modified Salinity Brine Recovery Processes
CURRENT OPINION IN COLLOID & INTERFACE SCIENCE
2020; 50
View details for DOI 10.1016/j.cocis.2020.101393
View details for Web of Science ID 000600601300011
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Application of Digital Volume Correlation to X-ray Computed Tomography Images of Shale
ENERGY & FUELS
2020; 34 (11): 13636–49
View details for DOI 10.1021/acs.energyfuels.0c02305
View details for Web of Science ID 000592961700027
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Pore-network modeling of single-phase reactive transport and dissolution pattern evaluation
ADVANCES IN WATER RESOURCES
2020; 145
View details for DOI 10.1016/j.advwatres.2020.103741
View details for Web of Science ID 000579002600008
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Effect of Pressure on Crude-Oil Kinetics During In Situ Combustion
ENERGY & FUELS
2020; 34 (10): 12103–17
View details for DOI 10.1021/acs.energyfuels.0c01679
View details for Web of Science ID 000582567000024
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Deep learning for automated characterization of pore-scale wettability
ADVANCES IN WATER RESOURCES
2020; 144
View details for DOI 10.1016/j.advwatres.2020.103708
View details for Web of Science ID 000567539100005
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Population-balance modeling of CO2 foam for CCUS using nanoparticles
JOURNAL OF NATURAL GAS SCIENCE AND ENGINEERING
2020; 80
View details for DOI 10.1016/j.jngse.2020.103378
View details for Web of Science ID 000549567300007
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Permeability and Porosity Evolution of Organic-Rich Shales from the Green River Formation as a Result of Maturation
SPE JOURNAL
2020; 25 (3): 1377–1405
View details for Web of Science ID 000576602600022
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Thermal Imaging To Visualize and Characterize Combustion Fronts in Porous Media
INDUSTRIAL & ENGINEERING CHEMISTRY RESEARCH
2020; 59 (5): 2181–91
View details for DOI 10.1021/acs.iecr.9b05737
View details for Web of Science ID 000512223600043
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Spontaneous fingering between miscible fluids
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
2020; 584
View details for DOI 10.1016/j.colsurfa.2019.123943
View details for Web of Science ID 000499647200023
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Investigating fracture propagation characteristics in shale using sc-CO2 and water with the aid of X-ray Computed Tomography
Journal of Natural Gas Science and Engineering
2020
View details for DOI 10.1016/j.jngse.2020.103736
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Pore Network Investigation of Trapped Gas and Foam Generation Mechanisms
TRANSPORT IN POROUS MEDIA
2020; 131 (1): 289–313
View details for DOI 10.1007/s11242-018-01224-4
View details for Web of Science ID 000512044800015
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Investigation of the Effects of Select Metal Nanoparticles on Heavy Oil Combustion in Porous Media
ENERGY & FUELS
2020; 34 (1): 130–41
View details for DOI 10.1021/acs.energyfuels.9b03252
View details for Web of Science ID 000508470500012
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Nanoparticle delivery to porous media via emulsions and thermally induced phase inversion
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
2019; 581
View details for DOI 10.1016/j.colsurfa.2019.123614
View details for Web of Science ID 000487764400001
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Modeling Steady-State Foam Flow: Hysteresis and Backward Front Movement
ENERGY & FUELS
2019; 33 (11): 11353–63
View details for DOI 10.1021/acs.energyfuels.9b01842
View details for Web of Science ID 000499741900094
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Spontaneous clay Pickering emulsification
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
2019; 577: 158–66
View details for DOI 10.1016/j.colsurfa.2019.05.030
View details for Web of Science ID 000477008000020
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The diffusion of water through oil contributes to spontaneous emulsification during low salinity waterflooding
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2019; 179: 606–14
View details for DOI 10.1016/j.petrol.2019.04.041
View details for Web of Science ID 000470109500051
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Doctrines and realities in viscous and heavy-oil reservoir engineering
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2019; 178: 1164–77
View details for DOI 10.1016/j.petrol.2019.03.044
View details for Web of Science ID 000466615500098
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Investigation of the effects of ions on short-range non-DLVO forces at the calcite/brine interface and implications for low salinity oil-recovery processes.
Journal of colloid and interface science
2019; 552: 295–311
Abstract
A primary question investigated in this study is the influence of brine chemistry on the behavior of short-range non-DLVO (e.g., hydration, discrete ion charge effects, and so on) forces at calcite surfaces. Specifically, how do wetting films containing Na+ differ from those containing Mg2+? Force-distance spectroscopy as measured by atomic force microscopy is used to probe short-range non-DLVO forces in various single-salt and multiple-salt electrolyte solutions. Experimental results reveal that, in single-component solutions, a greater concentration of Na+ ions decreases the decay length of short-range repulsion while a greater concentration of Mg2+ ions increases decay length. These results imply that Na+ ions reduce the affinity of calcite surfaces for water whereas Mg2+ ions make calcite more hydrophilic. Importantly, the relationship between the behavior of non-DLVO forces at small separations and concentrations of ions is not monotonic in multiple-component brines. Our observations support the hypothesis that Na+ ions disturb the interfacial water structure of calcite while Mg2+ ions are arranged farther away from the surface. Results obtained here may have implications for the design of so-called low salinity waterfloods where the composition of brines used for crude oil recovery is manipulated to increase oil recovery.
View details for DOI 10.1016/j.jcis.2019.05.049
View details for PubMedID 31132632
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Recovery efficiency of a 28 degrees API crude-oil system as a function of voidage replacement ratio
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2019; 175: 1063–87
View details for DOI 10.1016/j.petrol.2019.01.028
View details for Web of Science ID 000458153000084
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Influence of Microcracks on Flow and Storage Capacities of Gas Shales at Core Scale
TRANSPORT IN POROUS MEDIA
2019; 127 (1): 53–84
View details for DOI 10.1007/s11242-018-1180-5
View details for Web of Science ID 000459472600003
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The Effect of Voidage-Displacement Ratio on Critical Gas Saturation
SPE JOURNAL
2019; 24 (1): 178–99
View details for DOI 10.2118/191383-PA
View details for Web of Science ID 000458509000012
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A systematic study of internal gas generation in shale source rocks using analog experiments
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2019; 173: 209–21
View details for DOI 10.1016/j.petrol.2018.10.006
View details for Web of Science ID 000455118800018
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Pore-scale visualization and characterization of viscous dissipation in porous media.
Journal of colloid and interface science
2019; 558: 269–79
Abstract
The effects of mutual transfer of momentum between two immiscible flowing fluids in porous media are not well understood nor predictable yet. From considerations at the pore-scale, it should be possible to determine whether and to what extent interfacial viscous coupling effects are significant.We visualize the velocity distributions inside immobile globules of wetting phase (water) while a non-wetting phase (oil) is injected. We investigate viscous coupling effects and their relationship with the viscosity ratio and the capillary number.Four regimes of viscous dissipation are identified: (i) a regime for which the fluid-fluid interface acts as a solid wall; (ii) a regime where the wetting phase is dragged in the direction of the imposed flow; (iii) and (iv) two regimes for which the trapped globule of water shows a recirculating motion due to the shear stress at the oil/water interface. We demonstrate the significant role of the lubricating effect and of the topology of the pore space on the magnitude of viscous dissipation. Importantly, for a viscosity ratio close to one and low capillary number, we demonstrate that viscous coupling effects should be incorporated into the existing Darcy's law formulation for two-phase flow in porous media.
View details for DOI 10.1016/j.jcis.2019.09.072
View details for PubMedID 31593860
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Mechanisms of multiphase reactive flow using biogenically calcite-functionalized micromodels
LAB ON A CHIP
2018; 18 (24): 3881–91
View details for DOI 10.1039/c8lc00793d
View details for Web of Science ID 000452320500016
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Mechanisms of multiphase reactive flow using biogenically calcite-functionalized micromodels.
Lab on a chip
2018
Abstract
Dissolution of carbonate minerals in porous media is important to many instances of subsurface flow, including geological carbon dioxide (CO2) sequestration, karst formation, and crude-oil reservoir stimulation and acidizing. Of particular interest, geological CO2 storage in deep carbonate reservoirs presents a significant long-term opportunity to mitigate atmospheric carbon emissions. The reactivity of carbonate reservoirs, however, may negatively impact storage formation integrity and hence jeopardize sequestered CO2 storage security. In this work, we develop a novel biogenically calcite-functionalized microvisual device to study the fundamental pore-scale reactive transport dynamics in carbonate formations. Importantly, we discover a new microscale mechanism that dictates the overall behavior of the reactive transport phenomenon, where the reaction product, CO2, due to carbonate rock dissolution forms a separate, protective phase that engulfs the carbonate rock grain and reduces further dissolution. The presence of the separate, protective CO2 phase determines overall dissolution patterns in the storage reservoir and leads to formation of preferential leakage paths. We scale these results using nondimensional numbers to demonstrate their influence on industrial CO2 storage security, safety, and capacity.
View details for PubMedID 30462124
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Pore-scale modelling of multiphase reactive flow: application to mineral dissolution with production of CO2
JOURNAL OF FLUID MECHANICS
2018; 855: 616–45
View details for DOI 10.1017/jfm.2018.655
View details for Web of Science ID 000445208400002
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Pulsating linear in situ combustion: why do we often observe oscillatory behavior?
COMPUTATIONAL GEOSCIENCES
2018; 22 (4): 1115–34
View details for DOI 10.1007/s10596-018-9741-9
View details for Web of Science ID 000438821700010
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An experimental platform for triaxial high-pressure/high-temperature testing of rocks using computed tomography
REVIEW OF SCIENTIFIC INSTRUMENTS
2018; 89 (4): 045101
Abstract
A conventional high-pressure/high-temperature experimental apparatus for combined geomechanical and flow-through testing of rocks is not X-ray compatible. Additionally, current X-ray transparent systems for computed tomography (CT) of cm-sized samples are limited to design temperatures below 180 °C. We describe a novel, high-temperature (>400 °C), high-pressure (>2000 psi/>13.8 MPa confining, >10 000 psi/>68.9 MPa vertical load) triaxial core holder suitable for X-ray CT scanning. The new triaxial system permits time-lapse imaging to capture the role of effective stress on fluid distribution and porous medium mechanics. System capabilities are demonstrated using ultimate compressive strength (UCS) tests of Castlegate sandstone. In this case, flooding the porous medium with a radio-opaque gas such as krypton before and after the UCS test improves the discrimination of rock features such as fractures. The results of high-temperature tests are also presented. A Uintah Basin sample of immature oil shale is heated from room temperature to 459 °C under uniaxial compression. The sample contains kerogen that pyrolyzes as temperature rises, releasing hydrocarbons. Imaging reveals the formation of stress bands as well as the evolution and connectivity of the fracture network within the sample as a function of time.
View details for PubMedID 29716377
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An optimization algorithm for evaluation of kinetic parameters for crude oil combustion
Journal of Petroleum Science and Engineering
2018; 169: 241-257
View details for DOI 10.1016/j.petrol.2018.04.076
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Effects of Image Resolution on Sandstone Porosity and Permeability as Obtained from X-Ray Microscopy
Transport in Porous Media
2018
View details for DOI 10.1007/s11242-018-1189-9
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Determination of pore-scale hydrate phase equilibria in sediments using lab-on-a-chip technology
LAB ON A CHIP
2017; 17 (23): 4070–76
Abstract
We present an experimental protocol for fast determination of hydrate stability in porous media for a range of pressure and temperature (P, T) conditions. Using a lab-on-a-chip approach, we gain direct optical access to dynamic pore-scale hydrate formation and dissociation events to study the hydrate phase equilibria in sediments. Optical pore-scale observations of phase behavior reproduce the theoretical hydrate stability line with methane gas and distilled water, and demonstrate the accuracy of the new method. The procedure is applicable for any kind of hydrate transitions in sediments, and may be used to map gas hydrate stability zones in nature.
View details for DOI 10.1039/c7lc00719a
View details for Web of Science ID 000415989600012
View details for PubMedID 29067399
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Measurements and simulation of liquid films during drainage displacements and snap-off in constricted capillary tubes
JOURNAL OF COLLOID AND INTERFACE SCIENCE
2017; 507: 279–89
Abstract
When a wetting liquid is displaced by air in a capillary tube, a wetting film develops between the tube wall and the air that is responsible for the snap-off mechanism of the gas phase. By dissolving a dye in the wetting phase it is possible to relate a measure of the absorbance in the capillary to the thickness of liquid films. These data could be used to compare with cutting edge numerical simulations of the dynamics of snap-off for which experimental and numerical data are lacking. Drainage experiments in constricted capillary tubes were performed where a dyed wetting liquid is displaced by air for varying flow rates. We developed an optical method to measure liquid film thicknesses that range from 3 to 1000μm. The optical measures are validated by comparison with both theory and direct numerical simulations. In a constricted capillary tube we observed, both experimentally and numerically, a phenomenon of snap-off coalescence events in the vicinity of the constriction that bring new insights into our understanding and modeling of two-phase flows. In addition, the good agreement between experiments and numerical simulations gives confidence to use the numerical method for more complex geometries in the future.
View details for PubMedID 28802195
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Experimental investigation and Grand Canonical Monte Carlo simulation of gas shale adsorption from the macro to the nano scale
JOURNAL OF NATURAL GAS SCIENCE AND ENGINEERING
2017; 48: 119–37
View details for DOI 10.1016/j.jngse.2016.12.024
View details for Web of Science ID 000417003200011
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Multiscale Imaging of Gas Storage in Shales
SPE JOURNAL
2017; 22 (6): 1760–77
View details for Web of Science ID 000418011600003
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NonArrhenius kinetics for reactive transport simulations of in situ combustion
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2017; 157: 570–80
View details for DOI 10.1016/j.petrol.2017.07.047
View details for Web of Science ID 000410624800046
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Creation of a dual-porosity and dual-depth micromodel for the study of multiphase flow in complex porous media
LAB ON A CHIP
2017; 17 (8): 1462-1474
Abstract
Silicon-based microfluidic devices, so-called micromodels in this application, are particularly useful laboratory tools for the direct visualization of fluid flow revealing pore-scale mechanisms controlling flow and transport phenomena in natural porous media. Current microfluidic devices with uniform etched depths, however, are limited when representing complex geometries such as the multiple-scale pore sizes common in carbonate rocks. In this study, we successfully developed optimized sequential photolithography to etch micropores (1.5 to 21 μm width) less deeply than the depth of wider macropores (>21 μm width) to improve the structural realism of an existing single-depth micromodel with a carbonate-derived pore structure. Surface profilimetry illustrates the configuration of the dual-depth dual-porosity micromodel and is used to estimate the corresponding pore volume change for the dual-depth micromodel compared to the equivalent uniform- or single-depth model. The flow characteristics of the dual-depth dual-porosity micromodel were characterized using micro-particle image velocimetry (μ-PIV), relative permeability measurements, and pore-scale observations during imbibition and drainage processes. The μ-PIV technique provides insights into the fluid dynamics within microfluidic channels and relevant fluid velocities controlled predominantly by changes in etching depth. In addition, the reduction of end-point relative permeability for both oil and water in the new dual-depth dual-porosity micromodel compared to the equivalent single-depth micromodel implies more realistic capillary forces occurring in the new dual-depth micromodel. Throughout the imbibition and drainage experiments, the flow behaviors of single- and dual-depth micromodels are further differentiated using direct visualization of the trapped non-wetting phase and the preferential mobilization of the wetting phase in the dual-depth micromodel. The visual observations agree with the relative permeability results. These findings indicate that dual-porosity and dual-depth micromodels have enhanced physical realism that is pertinent to oil recovery processes in complex porous media.
View details for DOI 10.1039/c6lc01343k
View details for Web of Science ID 000399213700008
View details for PubMedID 28294224
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Analysis of the effects of copper nanoparticles on in-situ combustion of extra heavy-crude oil
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2017; 152: 406-415
View details for DOI 10.1016/j.petrol.2017.02.018
View details for Web of Science ID 000401042000033
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CO2 Storage and Flow Capacity Measurements on Idealized Shales from Dynamic Breakthrough Experiments
ENERGY & FUELS
2017; 31 (2): 1193-1207
View details for DOI 10.1021/acs.energyfuels.6b02286
View details for Web of Science ID 000394560900014
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Multiscale pore structure characterization of middle east carbonates
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2016; 146: 570-583
View details for DOI 10.1016/j.petrol.2016.07.018
View details for Web of Science ID 000384854200054
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Pore-level hydrate formation mechanisms using realistic rock structures in high-pressure silicon micromodels
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
2016; 53: 178-186
View details for DOI 10.1016/j.ijggc.2016.06.017
View details for Web of Science ID 000383725700018
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Visualization and Quantification of Thermally Induced Porosity Alteration of Immature Source Rock Using X-ray Computed Tomography
ENERGY & FUELS
2016; 30 (10): 8141-8149
View details for DOI 10.1021/acs.energyfuels.6b01430
View details for Web of Science ID 000386107200038
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In-Situ Visualization of Multidimensional Imbibition in Dual-Porosity Carbonates
SPE JOURNAL
2016; 21 (5): 1631-1642
View details for Web of Science ID 000393303000011
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Particle velocimetry analysis of immiscible two-phase flow in micromodels
ADVANCES IN WATER RESOURCES
2016; 95: 199-211
View details for DOI 10.1016/j.adywatres.2015.08.015
View details for Web of Science ID 000383299300016
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An Experimental Investigation of Viscous-Oil Recovery Efficiency as a Function of Voidage-Replacement Ratio
SPE JOURNAL
2016; 21 (4): 1236-1253
View details for Web of Science ID 000393300000013
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Experimental Study of Foam Generation, Sweep Efficiency, and Flow in a Fracture Network
SPE JOURNAL
2016; 21 (4): 1140-1150
View details for Web of Science ID 000393300000005
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Direct visualization of pore-scale fines migration and formation damage during low-salinity waterflooding
JOURNAL OF NATURAL GAS SCIENCE AND ENGINEERING
2016; 34: 1276-1283
View details for DOI 10.1016/j.jngse.2016.07.055
View details for Web of Science ID 000384390300113
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Understanding the role of brine ionic composition on oil recovery by assessment of wettability from colloidal forces
ADVANCES IN COLLOID AND INTERFACE SCIENCE
2016; 233: 126-138
Abstract
The impact of injection brine salinity and ionic composition on oil recovery has been an active area of research for the past 25years. Evidence from laboratory studies and field tests suggests that implementing certain modifications to the ionic composition of the injection brine leads to greater oil recovery. The role of salinity modification is attributed to its ability to shift wettability of a rock surface toward water wetness. The amount of trapped oil released depends on the nature of rock, oil, and brine surface interactions. Reservoir rocks exhibit different affinities to fluids. Carbonates show stronger adsorption of oil films as opposed to the strongly water-wet and mixed-wet sandstones. The concentration of divalent ions and total salinity of the injection brine are other important factors to consider. Accordingly, this paper provides a review of laboratory and field studies of the role of brine composition on oil recovery from carbonaceous rock as well as rationalization of results using DLVO (Derjaguin, Landau, Verwey and Overbeek) theory of surface forces. DLVO evaluates the contribution of each component of the oil/brine/rock system to the wettability. Measuring zeta potential of each pair of surfaces by a charged particle suspension method is used to estimate double layer forces, disjoining pressure, and contact-angle. We demonstrate the applicability of the DLVO approach by showing a comprehensive experimental study that investigates the effect of divalent ions in carbonates, and uses disjoining pressure results to rationalize observations from core flooding and direct contact-angle measurements.
View details for DOI 10.1016/j.cis.2015.08.004
View details for Web of Science ID 000379564300009
View details for PubMedID 26344867
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Pore-level mechanics of foam generation and coalescence in the presence of oil
ADVANCES IN COLLOID AND INTERFACE SCIENCE
2016; 233: 65-82
Abstract
The stability of foam in porous media is extremely important for realizing the advantages of foamed gas on gas mobility reduction. Foam texture (i.e., bubbles per volume of gas) achieved is dictated by foam generation and coalescence processes occurring at the pore-level. For foam injection to be widely applied during gas injection projects, we need to understand these pore-scale events that lead to foam stability/instability so that they are modeled accurately. Foam flow has been studied for decades, but most efforts focused on studying foam generation and coalescence in the absence of oil. Here, the extensive existing literature is reviewed and analyzed to identify open questions. Then, we use etched-silicon micromodels to observe foam generation and coalescence processes at the pore-level. Special emphasis is placed on foam coalescence in the presence of oil. For the first time, lamella pinch-off as described by Myers and Radke [40] is observed in porous media and documented. Additionally, a new mechanism coined "hindered generation" is found. Hindered generation refers to the role oil plays in preventing the successful formation of a lamella following snap-off near a pore throat.
View details for DOI 10.1016/j.cis2015.10.008
View details for Web of Science ID 000379564300005
View details for PubMedID 26548502
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Characterization and Measurement of Multiscale Gas Transport in Shale-Core Samples
SPE JOURNAL
2016; 21 (2): 573-588
View details for Web of Science ID 000385254100020
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Characterization of scalar mixing in dense gaseous jets using X-ray computed tomography
EXPERIMENTS IN FLUIDS
2015; 56 (10)
View details for DOI 10.1007/s00348-015-2057-9
View details for Web of Science ID 000363486500009
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Functionalization of micromodels with kaolinite for investigation of low salinity oil-recovery processes.
Lab on a chip
2015; 15 (16): 3314-3325
Abstract
Sandstone formations are ubiquitous in both aquifers and petroleum reservoirs, of which clay is a major constituent. The release of clay particles from pore surfaces as a result of reduced injection fluid salinity can greatly modify the recovery of hydrocarbons from subsurface formations by shifting the wettability properties of the rock. In this paper we demonstrate a microfluidic approach whereby kaolinite is deposited into a two-dimensional microfluidic network (micromodel) to enable direct pore-scale, real-time visualization of fluid-solid interactions with representative pore-geometry and realistic surface interactions between the reservoir fluids and the formation rock. Structural characterization of deposited kaolinite particles agrees well with natural modes of occurrence in Berea sandstones; hence, the clay deposition method developed in this work is validated. Specifically, more than 90% of the deposited clay particles formed pore-lining structures and the remainder formed pore bridging structures. Further, regions of highly concentrated clay deposition likely leading to so-called Dalmatian wetting properties were found throughout the micromodel. Two post-deposition treatments are described whereby clay is adhered to the silicon surface reversibly and irreversibly resulting in microfluidic systems that are amenable to studies on (i) the fundamental mechanisms governing the increased oil recovery during low salinity waterfloods and (ii) the effect of a mixed-wet surface on oil recovery, respectively. The reversibly functionalized platform is used to determine the conditions at which stably adhered clay particles detach. Specifically, injection brine salinity below 6000 ppm of NaCl induced kaolinite particle release from the silicon surface. Furthermore, when applied to an aged system with crude oil, the low salinity waterflood recovered an additional 14% of the original oil in place compared to waterflooding with the formation brine.
View details for DOI 10.1039/c5lc00544b
View details for PubMedID 26151880
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Imaging-Based Characterization of Calcite-Filled Fractures and Porosity in Shales
SPE JOURNAL
2015; 20 (4): 810-823
View details for Web of Science ID 000364541700012
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Microvisual investigation of polymer retention on the homogeneous pore network of a micromodel
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2015; 128: 115-127
View details for DOI 10.1016/j.petrol.2015.02.004
View details for Web of Science ID 000353744200012
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Pore-level foam generation and flow for mobility control in fractured systems
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
2015; 468: 184-192
View details for DOI 10.1016/j.colsurfa.2014.12.043
View details for Web of Science ID 000349446500022
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An experimental investigation of the in-situ combustion behavior of Karamay crude oil
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2015; 127: 82-92
View details for DOI 10.1016/j.petrol.2015.01.005
View details for Web of Science ID 000351782400007
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A Reaction Model-Free Approach for In Situ Combustion Calculations: 1-Kinetics Prediction
TRANSPORT IN POROUS MEDIA
2015; 107 (2): 507-525
View details for DOI 10.1007/s11242-014-0451-z
View details for Web of Science ID 000351398700012
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Kinetics Oxidation of Heavy Oil. 2. Application of Genetic Algorithm for Evaluation of Kinetic Parameters
ENERGY & FUELS
2015; 29 (2): 1119-1129
View details for DOI 10.1021/ef501392k
View details for Web of Science ID 000349943300073
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Functionalization of micromodels with kaolinite for investigation of low salinity oil-recovery processes
LAB ON A CHIP
2015; 15 (16): 3314-3325
View details for DOI 10.1039/c5lc00544b
View details for Web of Science ID 000358609500008
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Gas Sorption and the Consequent Volumetric and Permeability Change of Coal I: Experimental
TRANSPORT IN POROUS MEDIA
2014; 105 (2): 371-389
View details for DOI 10.1007/s11242-014-0373-9
View details for Web of Science ID 000344600200005
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Fines migration and compaction in diatomaceous rocks
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2014; 122: 108-118
View details for DOI 10.1016/j.petrol.2014.06.024
View details for Web of Science ID 000345182300011
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Gas Sorption and the Consequent Volumetric and Permeability Change of Coal II: Numerical Modeling
TRANSPORT IN POROUS MEDIA
2014; 105 (1): 23-42
View details for DOI 10.1007/s11242-014-0356-x
View details for Web of Science ID 000342497600002
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Klinkenberg effect on predicting and measuring helium permeability in gas shales
INTERNATIONAL JOURNAL OF COAL GEOLOGY
2014; 123: 62-68
View details for DOI 10.1016/j.coal.2013.09.006
View details for Web of Science ID 000332820700007
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Consistency Measures for Isoconversional Interpretation of In-Situ Combustion Reaction Kinetics
ENERGY & FUELS
2014; 28 (2): 868-876
View details for DOI 10.1021/ef4020235
View details for Web of Science ID 000331861800017
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CT Imaging of Low-Permeability, Dual-Porosity Systems Using High X-ray Contrast Gas
Transport in Porous Media
2014; 101 (1): 81-97
View details for DOI 10.1007/s11242-013-0232-0
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Solar-generated steam for oil recovery: Reservoir simulation, economic analysis, and life cycle assessment
ENERGY CONVERSION AND MANAGEMENT
2014; 77: 721-732
View details for DOI 10.1016/j.enconman.2013.10.026
View details for Web of Science ID 000330494600076
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CT Imaging of Low-Permeability, Dual-Porosity Systems Using High X-ray Contrast Gas
TRANSPORT IN POROUS MEDIA
2014; 101 (1): 81-97
View details for DOI 10.1007/s11242-013-0232-0
View details for Web of Science ID 000328208700006
- (Submitted) Solar-Generated Steam for Oil Recovery: Reservoir Simulation, Economic Analysis, and Life Cycle Assessment Energy Conversion and Management 2014
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Fuel Formation and Conversion During In-Situ Combustion of Crude Oil
SPE JOURNAL
2013; 18 (6): 1217-1228
View details for Web of Science ID 000329265500018
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An induction reactor for studying crude-oil oxidation relevant to in situ combustion.
Review of scientific instruments
2013; 84 (7): 075115-?
Abstract
In a conventional ramped temperature oxidation kinetics cell experiment, an electrical furnace is used to ramp temperature at a prescribed rate. Thus, the heating rate of a kinetics cell experiment is limited by furnace performance to heating rates of about 0.5-3 °C/min. A new reactor has been designed to overcome this limit. It uses an induction heating method to ramp temperature. Induction heating is fast and easily controlled. The new reactor covers heating rates from 1 to 30 °C/min. This is the first time that the oxidation profiles of a crude oil are available over such a wide range of heating rate. The results from an induction reactor and a conventional kinetics cell at roughly 2 °C/min are compared to illustrate consistency between the two reactors. The results at low heating rate are the same as the conventional kinetics cell. As presented in the paper, the new reactor couples well with the isoconversional method for interpretation of reaction kinetics.
View details for DOI 10.1063/1.4815827
View details for PubMedID 23902114
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An induction reactor for studying crude-oil oxidation relevant to in situ combustion
REVIEW OF SCIENTIFIC INSTRUMENTS
2013; 84 (7)
View details for DOI 10.1063/1.4815827
View details for Web of Science ID 000322602200078
View details for PubMedID 23902114
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Wettability Alteration of a Heavy Oil/Brine/Carbonate System with Temperature
ENERGY & FUELS
2013; 27 (6): 2984-2998
View details for DOI 10.1021/ef400204k
View details for Web of Science ID 000320911200014
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Pore-Scale Evaluation of Polymers Displacing Viscous Oil-Computational-Fluid-Dynamics Simulation of Micromodel Experiments
SPE RESERVOIR EVALUATION & ENGINEERING
2013; 16 (2): 144-154
View details for Web of Science ID 000319532500003
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Improved Predictability of In-Situ-Combustion Enhanced Oil Recovery
SPE RESERVOIR EVALUATION & ENGINEERING
2013; 16 (2): 172-182
View details for Web of Science ID 000319532500005
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Nonequilibrium Effects and Multiphase Flow in Porous Media
TRANSPORT IN POROUS MEDIA
2013; 97 (3): 373-394
View details for DOI 10.1007/s11242-013-0129-y
View details for Web of Science ID 000316025200006
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Modification of heavy-oil rheology via alkaline solutions
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2013; 103: 41-50
View details for DOI 10.1016/j.petrol.2013.02.009
View details for Web of Science ID 000320220300005
- Solar-Generated Steam for Heavy-Oil Recovery: A Coupled Geomechanical and Reservoir Modeling Analysis SPE Western Regional Meeting 2013
- An Experimental Investigation of the In-Situ Combustion Behavior of Karamay Crude Oil SPE Western Regional Meeting 2013
- Optimal Voidage Replacement Ratio for Viscous and Heavy Oil Reservoirs SPE Western Regional Meeting 2013
- History and Application of Resistance Electrical Heaters in Downhole Oil Field Applications SPE Western Regional Meeting 2013
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Experiments and analysis of drainage displacement processes relevant to carbon dioxide injection
PHYSICAL REVIEW E
2012; 86 (6)
Abstract
The motivation for this work is a dramatically improved understanding of the fluid mechanics of drainage processes with applications such as CO_{2} storage in saline aquifers and water-alternating-gas injection as an enhanced oil recovery method. In this paper we present in situ distributions of wetting and nonwetting fluids obtained during core-scale two-phase immiscible drainage experiments. The ratio of the viscosity of the resident fluid to that of the invading fluid varies across a range of 0.43 to 150. Saturation distributions observed during dynamic displacement experiments are surprisingly smooth and do not display only one or a few dominant fingers, contrary to the indications of the current literature. The analysis of the saturation distribution using the fractal dimensions of the dynamic three-dimensional saturation distributions suggests that the constitutive relationships for porous media, namely, the relative permeability functions, are history dependent. Accordingly, it is suggested that the nonlinear, unstable flow regime is the regime where efforts to improve physical understanding must be focused.
View details for DOI 10.1103/PhysRevE.86.066310
View details for Web of Science ID 000312297400004
View details for PubMedID 23368041
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A Study of Microscale Gas Trapping Using Etched Silicon Micromodels
TRANSPORT IN POROUS MEDIA
2012; 95 (3): 647-668
View details for DOI 10.1007/s11242-012-0067-0
View details for Web of Science ID 000310744900010
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Modeling foam displacement in fractures
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2012; 100: 50-58
View details for DOI 10.1016/j.petrol.2012.11.018
View details for Web of Science ID 000315311400008
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Experiments and Analysis of Multiscale Viscous Fingering During Forced Imbibition
SPE Annual Technical Conference and Exhibition
SOC PETROLEUM ENG. 2012: 1142–59
View details for Web of Science ID 000313300500016
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Emerging challenges and potential futures for thermally enhanced oil recovery
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2012; 98-99: 130-143
View details for DOI 10.1016/j.petrol.2012.08.004
View details for Web of Science ID 000327682900013
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Creation of a dual-porosity micromodel for pore-level visualization of multiphase flow
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2012; 86-87: 27-38
View details for DOI 10.1016/j.petrol.2012.03.012
View details for Web of Science ID 000305820700003
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Executive Summary
SPE JOURNAL
2012; 17 (1): 7-7
View details for Web of Science ID 000301471300001
- Uncertainty Analysis on In-Situ Combustion Simulations Using Experimental Design SPE Western Regional Meeting 2012
- Pore-Scale Evaluation of Polymers Displacing Viscous Oil – Computational Fluid Dynamics Simulation of Micromodel Experiments, SPE 154169 Proceedings of the Eighteenth SPE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, USA, 14–18 April 2012 2012
- An X-Ray CT Study of Multidimensional Imbibition in Dual Porosity Carbonates SPE Annual Technical Conference and Exhibition 2012
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Emerging Challenges and Potential Futures for Thermally Enhanced Oil Recovery
Journal of Petroleum Science & Engineering
2012: 98-99 130-143
View details for DOI 10.1016/j.petrol.2012.08.004
- Microvisual Investigation of Foam Flow in Ideal Fractures: Role of Fracture Aperture and Surface Roughness SPE Annual Technical Conference and Exhibition 2012
- Solar-Generated Steam for Oil Recovery: Reservoir Simulation, Economic Analysis, and Life Cycle Assessment, SPE Western Regional Meeting 2012
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Kinetics Oxidation of Heavy Oil. 1. Compositional and Full Equation of State Model
ENERGY & FUELS
2011; 25 (11): 4886-4895
View details for DOI 10.1021/ef200365y
View details for Web of Science ID 000297001400003
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Combustion Kinetics of Heavy Oils in Porous Media
ENERGY & FUELS
2011; 25 (10): 4438-4451
View details for DOI 10.1021/ef200680t
View details for Web of Science ID 000296212900024
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Predictability of Crude Oil In-Situ Combustion by the Isoconversional Kinetic Approach
SPE JOURNAL
2011; 16 (3): 537-547
View details for Web of Science ID 000294880600006
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In-Situ Combustion Dynamics Visualized With X-Ray Computed Tomography
SPE JOURNAL
2011; 16 (3): 524-536
View details for Web of Science ID 000294880600005
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A Microvisual Study of the Displacement of Viscous Oil by Polymer Solutions
SPE RESERVOIR EVALUATION & ENGINEERING
2011; 14 (3): 269-280
View details for Web of Science ID 000291519400001
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Temperature-Induced Fracture Reconsolidation of Diatomaceous Rock During Forced Water Imbibition
SPE RESERVOIR EVALUATION & ENGINEERING
2011; 14 (1): 45-59
View details for Web of Science ID 000287790300004
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Super insulated wells to protect permafrost during thermal oil recovery
INTERNATIONAL JOURNAL OF OIL GAS AND COAL TECHNOLOGY
2011; 4 (1): 4-30
View details for Web of Science ID 000295489900002
- Kinetic Cell and Combustion Tube Results for a Central European Crude Oil SPE Annual Technical Conference and Exhibition 2011
- Thermally Induced Fracture Reconsolidation of Diatomite Under No Flow Conditions Western North America Regional Meeting 2011
- Upscaling for Field-scale In-situ Combustion Simulation Western North America Regional Meeting 2011
- Improved Predictability of In-Situ Combustion Enhanced Oil Recovery Proceedings of the 2011 International Energy Agency EOR Symposium, Vienna Austria 17-19 October 2011 2011
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High Resolution Imaging of Unstable, Forced Imbibition in Berea Sandstone
TRANSPORT IN POROUS MEDIA
2011; 86 (2): 647-664
View details for DOI 10.1007/s11242-010-9643-3
View details for Web of Science ID 000286918900019
- Experiments and Analysis of Multiscale Viscous Fingering during Forced Imbibition, SPE-143946 Proceedings of the 2011 SPE Annual Technical Conference and Exhibition, Denver, CO 30 Oct - 2 Nov 2011
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A Microvisual Study of the Displacement of Viscous Oil by Polymer Solutions
SPE Reservoir Evaluation & Engineering
2011; 14 (3)
View details for DOI 10.2118/122400-pa
- A Combined Experimental and Simulation Workflow to Improve Predictability of In Situ Combustion Western North America Regional Meeting 2011
- Fuel Formation During In-Situ Combustion SPE Annual Technical Conference and Exhibition 2011
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Wettability estimation of low-permeability, siliceous shale using surface forces
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2010; 75 (1-2): 33-43
View details for DOI 10.1016/j.petrol.2010.10.008
View details for Web of Science ID 000286846200004
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Untitled
SPE JOURNAL
2010; 15 (3): 586-586
View details for Web of Science ID 000282070500001
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Time-Dependent Shape Factors for Uniform and Non-Uniform Pressure Boundary Conditions
TRANSPORT IN POROUS MEDIA
2010; 83 (3): 591-601
View details for DOI 10.1007/s11242-009-9461-7
View details for Web of Science ID 000278899400008
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Modeling Foam Displacement With the Local-Equilibrium Approximation: Theory and Experimental Verification
2008 SPE Annual Technical Conference and Exhibition
SOC PETROLEUM ENG. 2010: 171–83
View details for Web of Science ID 000280326600016
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Spontaneous countercurrent imbibition and forced displacement characteristics of low-permeability, siliceous shale rocks
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2010; 71 (1-2): 47-55
View details for DOI 10.1016/j.petrol.2010.01.003
View details for Web of Science ID 000276125300008
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Improving Steam-Assisted Gravity Drainage Using Mobility Control Foams: Foam Assisted-SAGD (FA-SAGD)
SPE Improved Oil Recovery Symposium
2010
View details for DOI 10.2118/129847-ms
- Storage of Greenhouse Gases in Oil and Gas Reservoirs Developments and Innovation in Carbon Capture and Storage (CCS) Technology edited by Maroto-Valer, M. M. Woodhead Publishing LTD, Cambridge, UK. 2010
- Inaccessible Pore Volume of Associative Polymer Floods SPE Improved Oil Recovery Symposium 2010
- Experimental Investigation of Oil Recovery From Siliceous Shale by Miscible CO2 Injection SPE Annual Technical Conference and Exhibition 2010
- Reservoir Simulation of Cyclic Steam Injection Including the Effects of Temperature Induced Wettability Alteration Western North America Regional Meeting 2010
- An Experimental Investigation Of In-Situ Combustion In Heterogeneous Media Canadian Unconventional Resources & International Petroleum Conference 2010
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Isoconversional Kinetic Analysis of the Combustion of Heavy Hydrocarbons
ENERGY & FUELS
2009; 23 (8): 4003-4015
View details for DOI 10.1021/ef900222w
View details for Web of Science ID 000269088300023
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Oil chemistry and its impact on heavy oil solution gas drive
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2009; 66 (1-2): 47-59
View details for DOI 10.1016/j.petrol.2009.01.005
View details for Web of Science ID 000265589700006
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Spontaneous imbibition and wettability characteristics of Powder River Basin coal
INTERNATIONAL JOURNAL OF COAL GEOLOGY
2009; 77 (1-2): 34-42
View details for DOI 10.1016/j.coal.2008.08.002
View details for Web of Science ID 000262555600006
- Isoconversional Kinetic Analysis of the Combustion of Heavy Hydrocarbons SPE Western Regional Meeting 2009
- Overview-Heavy Oil Journal of Petroleum Technology 2009; 61 (3): 76
- Spontaneous Countercurrent Imbibition and Forced Displacement Characteristics of Low-Permeability, Siliceous Shale Rocks SPE Western Regional Meeting 2009
- Thaw Front Dynamics and Super Insulated Wells for Thermal Recovery in Cold Environments SPE Western Regional Meeting 2009
- Pore-Level Mechanics of Forced and Spontaneous Imbibition of Aqueous Surfactant Solutions in Fractured Porous Media SPE Annual Technical Conference and Exhibition 2009
- The Displacement of Viscous Oil by Associative Polymer Solutions SPE Annual Technical Conference and Exhibition 2009
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Effects of Reservoir Heterogeneities on the Steam-Assisted Gravity-Drainage Process
SPE RESERVOIR EVALUATION & ENGINEERING
2008; 11 (5): 921-932
View details for Web of Science ID 000261045800013
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Sorption-induced permeability change of coal during gas-injection processes
SPE RESERVOIR EVALUATION & ENGINEERING
2008; 11 (4): 792-802
View details for Web of Science ID 000258936400015
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Laboratory and simulation investigation of enhanced coalbed methane recovery by gas injection
TRANSPORT IN POROUS MEDIA
2008; 73 (2): 141-159
View details for DOI 10.1007/s11242-007-9165-9
View details for Web of Science ID 000255198700002
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Authors' reply to discussion of interrelationship of temperature and wettability on the relative permeability of heavy oil in diatomaceous rocks
SPE RESERVOIR EVALUATION & ENGINEERING
2008; 11 (3): 437-438
View details for Web of Science ID 000257357200002
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Combination of well log and pore-scale data to predict petrophysical properties of diatomite
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2008; 60 (3-4): 133-149
View details for DOI 10.1016/j.petrol.2007.05.013
View details for Web of Science ID 000255445200001
- Alteration of Reservoir Diatomites by Hot Water Injection SPE Western Regional Meeting 2008
- Enhanced Oil Recovery Using Aqueous Phase Chemicals, Miscible Gas Injection, and Thermal Means, in Petroleum Engineering-Upstream Encyclopedia of Life Support Systems (EOLSS) edited by Mesini, E., Macini, P. 2008
- Polymer Augmented Waterflooding Encyclopedia of Petroleum Science & Engineering edited by Antos, G. J. Marcel Dekker, New York. 2008
- Overview-Heavy Oil Journal of Petroleum Technology 2008; 60 (3): 84
- Modeling Foam Displacement with the Local Equilibrium Approximation: Theory and Experiment Verification SPE Annual Technical Conference and Exhibition 2008
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Petroleum Recovery
Encyclopedia of Petroleum Science & Engineering
edited by Antos, G. J.
Marcel Dekker, New York. 2008
View details for DOI 10.1007/s11242-005-6093-4
- Foam Transport in Porous Media Encyclopedia of Petroleum Science & Engineering edited by Antos, G. J. Marcel Dekker, New York. 2008
- Laboratory investigation of the effect of solvent injection on in-situ combustion SOC PETROLEUM ENG. 2008: 153-163
- Immiscible Carbon Dioxide Displacement Encyclopedia of Petroleum Science & Engineering edited by Speight, J. G. Marcel Dekker, New York. 2008
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Experimental Investigation of Oil Recovery From Siliceous Shale by CO2 Injection
SPE Annual Technical Conference and Exhibition
2008
View details for DOI 10.2118/115679-ms
- Improved Analysis of the Kinetics of Crude-Oil In-Situ Combustion SPE Western Regional Meeting 2008
- Correlation of Cold Production Behavior with Acid/Base Number and Asphaltene Content of Heavy Oil, SPE 114196 Proceedings of the SPE Western Regional Meeting, Bakersfield, CA. 31 Mar - 2 Apr 2008 2008
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A pore-network-modeling approach to predict petrophysical properties of diatomaceous reservoir rock
2005 SPE Western Regional Meeting
SOC PETROLEUM ENG. 2007: 597–608
View details for Web of Science ID 000252462300003
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Verification of Roof snap off as a foam-generation mechanism in porous media at steady state
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
2007; 302 (1-3): 251-260
View details for DOI 10.1016/j.colsurfa.2007.02.035
View details for Web of Science ID 000247192300037
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Forced imbibition in natural porous media: Comparison between experiments and continuum models
PHYSICAL REVIEW E
2007; 75 (3)
Abstract
A well-characterized set of large-scale laboratory experiments is presented, illustrating forced imbibition displacements in the presence of irreducible wetting phase saturation in a cylindrical, homogeneous Berea sandstone rock. Experiments are designed to operate in the regime of compact microscopic flows and large-scale viscous instability. The distribution of fluid phases during the flow process is visualized by high-resolution computed tomography imaging. Linear stability analysis and high-accuracy numerical simulations are employed to analyze the ability of macroscopic continuum equations to provide a consistent approximation of the displacement process. The validity of the equilibrium relative permeability functions, which form the basis for the continuum model, is fundamentally related to the stability of the displacement process. It is shown that not only is the stable flow regime modeled accurately by existing continuum models, but the onset of instability as well as the initial unstable modes are also determined with reasonable accuracy for unstable flows. However, the continuum model is found to be deficient in the case of fully developed unstable flows.
View details for DOI 10.1103/PhysRevE.75.036305
View details for PubMedID 17500789
- Sorption-Induced Permeability Change of Coal During Gas-Injection Processes, SPE-109855 , Proceedings of the SPE Annual Technical Conference and Exhibition, Anaheim, CA 2007
- Overview-Heavy Oil Journal of Petroleum Technology 2007; 59 (4): 82
- Effects of Reservoir Heterogeneities on the Steam-Assisted Gravity Drainage Process SPE Annual Technical Conference and Exhibition 2007
- Multicomponent Sorption Modeling in ECBM Displacement Calculations SPE Annual Technical Conference and Exhibition 2007
- Oil Recovery and Fracture Reconsolidation of Diatomaceous Reservoir Rock by Water Imbibition at High Temperature SPE Annual Technical Conference and Exhibition 2007
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Time-dependent matrix-fracture shape factors for partially and completely immersed fractures
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2006; 54 (3-4): 149-163
View details for DOI 10.1016/j.petrol.2006.08.004
View details for Web of Science ID 000242822300005
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Trapped gas fraction during steady-state foam flow
2004 SPE Annual Technical Conference and Exhibition
SPRINGER. 2006: 287–307
View details for DOI 10.1007/s11242-005-6093-4
View details for Web of Science ID 000243647300007
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Estimation of dynamic relative permeability and capillary pressure from countercurrent imbibition experiments
TRANSPORT IN POROUS MEDIA
2006; 65 (1): 31-51
View details for DOI 10.1007/s11242-005-6092-5
View details for Web of Science ID 000240724700002
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A laboratory investigation of temperatrue-induced sand consolidation
2005 SPE Western Regional Meeting
SOC PETROLEUM ENG. 2006: 206–15
View details for Web of Science ID 000238588900008
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Wettability alteration and oil recovery by water imbibition at elevated temperatures
8th International Symposium on Reservoir Wettability
ELSEVIER SCIENCE BV. 2006: 131–48
View details for DOI 10.1016/j.petrol.2006.03.017
View details for Web of Science ID 000238929500009
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Heavy-oil solution gas drive in consolidated and unconsolidated rock
2004 SPE International Thermal Operations and Heavy Oil Symposium/Western Regional Meeting
SOC PETROLEUM ENG. 2006: 259–68
View details for Web of Science ID 000238588900013
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Interrelationship of temperature and wettability on the relative permeability of heavy oil in diatomaceous rocks
2005 SPE Western Regional Meeting
SOC PETROLEUM ENG. 2006: 239–50
View details for Web of Science ID 000238440900005
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Nonequilibrium effects during spontaneous imbibition
TRANSPORT IN POROUS MEDIA
2006; 63 (1): 127-146
View details for DOI 10.1007/s11242-005-3327-4
View details for Web of Science ID 000236514700007
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A micromodel investigation of two-phase matrix-fracture transfer mechanisms
WATER RESOURCES RESEARCH
2006; 42 (3)
View details for DOI 10.1029/2004WR003918
View details for Web of Science ID 000236272800001
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An investigation of the effect of oil composition on heavy-oil solution gas drive
2003 SPE Annual Technical Conference and Exhibition
SOC PETROLEUM ENG. 2006: 58–70
View details for Web of Science ID 000236700900005
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Asphaltene deposition during steam-assisted gravity drainage: Effect of non-condensable gases
PETROLEUM SCIENCE AND TECHNOLOGY
2006; 24 (1): 69-92
View details for DOI 10.1081/LFT-200041109
View details for Web of Science ID 000235050900008
- Laboratory Investigation of the Effect of Solvent Injection on In-Situ Combustion, SPE 99752 Proceedings of the SPE Symposium on Improved Oil Recovery, Tulsa, OK Apr 22-26, 2006 2006
- Overview -Heavy Oil Journal of Petroleum Technology 2006; 58 (4): 97
- Interpretation of Heat Distribution, Remaining Oil Saturation, and Steamflood Potential of Block Wa38, Liaohe Field, SPE Annual Technical Conference and Exhibition 2006
- Laboratory Investigation of the Effect of Solvent Injection on In-Situ Combustion SPE/DOE Symposium on Improved Oil Recovery 2006
- Petroleum Coke The World Book Encyclopedia 2006; 15: X350
- The Role of Oil Chemistry on Cold Production of Heavy Oils SPE Annual Technical Conference and Exhibition 2006
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Time-Dependent Shape Factors for Partially and Completely Immersed Fractures
Journal of Petroleum Science and Engineering
2006; 54: 149-163
View details for DOI 10.1016/jpetrol.2006.08.004
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Mechanism of formation damage at elevated temperature
JOURNAL OF ENERGY RESOURCES TECHNOLOGY-TRANSACTIONS OF THE ASME
2005; 127 (3): 171-180
View details for DOI 10.1115/1.1924398
View details for Web of Science ID 000231636600002
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Geologic storage of carbon dioxide and enhanced oil recovery. I. Uncertainty quantification employing a streamline based proxy for reservoir flow simulation
ENERGY CONVERSION AND MANAGEMENT
2005; 46 (11-12): 1920-1940
View details for DOI 10.1016/j.enconman.2004.09.008
View details for Web of Science ID 000228261900018
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Geologic storage of carbon dioxide and enhanced oil recovery. II. Cooptimization of storage and recovery
ENERGY CONVERSION AND MANAGEMENT
2005; 46 (11-12): 1941-1956
View details for DOI 10.1016/j.enconman.2004.09.009
View details for Web of Science ID 000228261900019
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Displacement front stability of steam injection into high porosity diatomite rock
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2005; 46 (4): 253-266
View details for DOI 10.1016/j.petrol.2005.01.004
View details for Web of Science ID 000228774700004
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A microvisual study of solution-gas-drive mechanisms in viscous oils
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2005; 46 (1-2): 101-119
View details for DOI 10.1016/j.petrol.2004.08.003
View details for Web of Science ID 000226784600007
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A direct sequential simulation approach to streamline-based history matching
7th International Geostatistics Congress
SPRINGER. 2005: 1077–1086
View details for Web of Science ID 000234961400112
- A Pore Network Modeling Approach to Predict Petrophysical Propoerties of Diatomaceous Reservoir Rock Proceedings of the SPE Western Regional Meeting 2005: 2005
- A Laboratory Investigation of Temperature Induced Sand Consolidation SPE Western Regional Meeting 2005
- Overview-Heavy Oil Journal of Petroleum Technology 2005; 57 (6): 62
- Matrix Fracture Shape Factors and Multiphase Flow Properties of Fractured Porous Media SPE Latin America and Caribbean Petroleum Engineering Conference 2005
- Improved In-Situ Combustion Performance with Metallic Salt Additives SPE Western Regional Meeting 2005
- Effect of Temperature on Relative Permeability for Heavy-Oil Diatomite Reservoirs SPE Western Regional Meeting 2005
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Increasing CO2 storage in oil recovery
ENERGY CONVERSION AND MANAGEMENT
2005; 46 (2): 293-311
View details for DOI 10.1016/j.enconman.20004.02.019
View details for Web of Science ID 000224606300010
- Laboratory and Simulation Investigation of Enhanced Coalbed Methane Recovery by Gas Injection SPE Annual Technical Conference and Exhibition 2005
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Electrical-heating-assisted recovery for heavy oil
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2004; 45 (3-4): 213-231
View details for DOI 10.1016/j.petrol.2004.06.005
View details for Web of Science ID 000226452000007
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Noncondensable gas steam-assisted gravity drainage
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2004; 45 (1-2): 83-96
View details for DOI 10.1016/j.petrol.2004.04.006
View details for Web of Science ID 000225705700008
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An experimental investigation of the effect of temperature on recovery of heavy oil from diatomite
SPE JOURNAL
2004; 9 (2): 163-?
View details for Web of Science ID 000222251600005
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Experiments and analysis of heavy-oil solution-gas drive
2001 SPE Annual Technical Conference and Exhibition
SOC PETROLEUM ENG. 2004: 217–29
View details for Web of Science ID 000222433900006
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Efficiency and oil recovery mechanisms of steam injection into low permeability, hydraulically fractured reservoirs
PETROLEUM SCIENCE AND TECHNOLOGY
2004; 22 (5-6): 537-564
View details for DOI 10.1081/LFT-120034187
View details for Web of Science ID 000221834300005
- Steamdrive Stability in High Porosity Rock SPE International Thermal Operations and Heavy Oil Symposium and Western Regional Meeting 2004
- Heavy-Oil Solution Gas Drive in Consolidated and Unconsolidated Rock SPE International Thermal Operations and Heavy Oil Symposium and Western Regional Meeting 2004
- Experimental Investigation and High Resolution Simulator of In-Situ Combustion: 1. Simulator Design and Improved Combustion With Metallic Additives SPE International Thermal Operations and Heavy Oil Symposium and Western Regional Meeting 2004
- Thermally Induced Fines Migration: Its Relationship to Wettability and Formation Damage, SPE 86937 SPE International Thermal Operations and Heavy Oil Symposium and Western Regional Meeting 2004
- Code Intercomparison Builds Confidence in Numerical Simulation Models for Geologic Disposal of CO2 Energy 2004; 29: 1431-1444
- Experimental Determination of Time-Dependent Matrix-Fracture Shape Factors for Different Geometries and Fracture Filling Regimes, SPE 92131 SPE International Petroleum Conference 2004
- Streamline-Based History Matching Using Geostatistical Constraints: Application to a Giant Mature Carbonate Reservoir SPE Annual Technical Conference and Exhibition 2004
- Microvisual Analysis of Matrix-Fracture Interaction SPE International Petroleum Conference in Mexico 2004
- Measurement and Theory of Gas Trapping in Porous Media During Steady-State Foam Flow SPE Annual Technical Conference and Exhibition, 2004
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Analytical theory of coalbed methane recovery by gas injection
2002 SPE/DOE Improved Oil Recovery Symposium
SOC PETROLEUM ENG. 2003: 371–79
View details for Web of Science ID 000187862600006
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Special issue - Honoring Professor W.E. Brigham - Preface
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2003; 39 (1-2): 1-3
View details for DOI 10.1016/S0920-4105(03)00036-6
View details for Web of Science ID 000184635600001
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A technique for measuring two-phase relative permeability in porous media via X-ray CT measurements
Brigham Symposium
ELSEVIER SCIENCE BV. 2003: 159–74
View details for DOI 10.1016/S0920-4105(03)00046-9
View details for Web of Science ID 000184635600011
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Foam mobility in heterogeneous porous media - (II: Experimental observations)
TRANSPORT IN POROUS MEDIA
2003; 52 (1): 37-49
View details for Web of Science ID 000181013100003
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Foam mobility in heterogeneous porous media - (I: Scaling concepts)
TRANSPORT IN POROUS MEDIA
2003; 52 (1): 17-35
View details for Web of Science ID 000181013100002
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A mechanistic modeling and experimental study of solution gas drive
TRANSPORT IN POROUS MEDIA
2003; 51 (3): 237-265
View details for Web of Science ID 000181013000001
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Integrating production history into reservoir models using streamline-based time-of-flight ranking
PETROLEUM GEOSCIENCE
2003; 9 (2): 163-174
View details for Web of Science ID 000183733800005
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Pressure-driven capillary snap-off of gas bubbles at low wetting-liquid content
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
2003; 212 (2-3): 99-108
View details for Web of Science ID 000180543600001
- An Investigation of the Effect of Oil Composition on Heavy Oil Solution Gas Drive SPE Annual Technical Conference and Exhibition 2003: 2003
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Computed Tomography in Petroleum Engineering Research
Geological Society, London, Special Publications
2003; 215: 23-28
View details for DOI 10.1144/GSL.SP.2003.215.01.03
- Time-Dependent Matrix-Fracture Shape Factors for Partially and Completely Immersed Fractures, SPE 84411 Proceedings of the SPE Annual Technical Conference and Exhibition, Denver, CO Oct. 5-8 2003
- Analytical Solutions for Coal-Bed Methane Displacement by Gas Injection SPE Journal 2003; 8 (4)
- ime Dependent Shape Factors for Uniform and Non-Uniform Pressure Boundary Conditions Geothermal Resources Council Annual Meeting 2003
- Computed Tomography in Petroleum Engineering Research Applications of X-ray Computed Tomography in the Geosciences edited by Mees, F., Swennen, R., Van Geet, M., Jacobs, P. Geological Society Publications. 2003
- Light-Oil Steamdrive in Fractured Low Permeability Reservoirs SPE Western Region/AAPG Pacific Section Joint Meeting 2003
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Experimental and analytical study of multidimensional imbibition in fractured porous media
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2002; 36 (1-2): 45-60
View details for Web of Science ID 000178598800004
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A geostatistical approach to streamline-based history matching
SPE JOURNAL
2002; 7 (3): 250-266
View details for Web of Science ID 000178119400004
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Heavy-oil solution gas drive: a laboratory study
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2002; 35 (1-2): 33-48
View details for Web of Science ID 000177167200003
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Scaling of counter-current imbibition processes in low-permeability porous media
6th International Symposium on Reservoir Wettability and Its Effect on Oil Recovery
ELSEVIER SCIENCE BV. 2002: 61–74
View details for Web of Science ID 000175595000007
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Screening criteria for CO2 storage in oil reservoirs
PETROLEUM SCIENCE AND TECHNOLOGY
2002; 20 (7-8): 841-866
View details for DOI 10.1081/LFT-120003717
View details for Web of Science ID 000177317900013
- Analytical Solutions for Coal-Bed Methane Displacement by Gas Injection, SPE 75255 Proceedings of the SPE/DOE Thirteenth Symposium on Improved Oil Recovery, Tulsa, OK April 13-17 2002
- Petroleum Recovery Encyclopedia of Petroleum Science and Engineering edited by Speight, J. G. Marcel Dekker, New York. 2002
- Wettability Alteration of Diatomite Induced by Hot-Fluid Injection SPE Annual Technical Conference and Exhibition 2002
- Polymer Augmented Waterflooding Encyclopedia of Petroleum Science and Engineering edited by Speight, J. G. Marcel Dekker, New York. 2002
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A Study of Steam-Assisted Gravity Drainage Performance in the Presence of Noncondensable Gases
SPE/DOE Improved Oil Recovery Symposium
2002
View details for DOI 10.2118/75130-ms
- Immiscible Carbon Dioxide Displacement Encyclopedia of Petroleum Science and Engineering edited by Speight, J. G. Marcel Dekker, New York. 2002
- Mechanistic Modeling of Solution-Gas Drive in Viscous Oils Journal of Petroleum Technology 2002; 53 (6): 48-49
- Experimental Study of Heavy Oil Production from Diatomite Core at Elevated Temperatures SPE/DOE Thirteenth Symposium on Improved Oil Recovery 2002
- Estimation of Foam Mobility in Heterogeneous Porous Media SPE/DOE Thirteenth Symposium on Improved Oil Recovery 2002
- Pore Microstructure and Fluid Distribution in a Diatomaceous Reservoir SPE/DOE Thirteenth Symposium on Improved Oil Recovery, 2002
- A Streamline Approach for Ranking Reservoir Models that Incorporates Production History SPE Annual Technical Conference and Exhibition 2002
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Surfactant concentration and end effects on foam flow in porous media
TRANSPORT IN POROUS MEDIA
2001; 43 (3): 511-536
View details for Web of Science ID 000169522500006
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A numerical analysis of the single-well steam assisted gravity drainage process (SW-SAGD)
PETROLEUM SCIENCE AND TECHNOLOGY
2001; 19 (7-8): 733-760
View details for Web of Science ID 000171635500001
- An Investigation of Counter-Current Imbibition Processes in Diatomite SPE Western Regional Meeting 2001
- Increasing CO2 Storage in Oil Recovery First National Conference on Carbon Sequestration 2001
- Water Infiltration in Fractured Systems: Experiments and Analytical Model SPE Annual Technical Conference and Exhibition 2001
- Direct Measurement of Dynamic Relative Permeability from CT-Monitored Spontaneous Imbibition Experiments SPE Annual Technical Conference and Exhibition 2001
- Countercurrent Imbibition Processes in Diatomite Journal of Petroleum Technology 2001; 53: 44
- Mechanistic Modeling of Solution Gas Drive in Viscous Oils SPE International Thermal Operations and Heavy Oil Symposium 2001
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Porosity and permeability evolution accompanying hot fluid injection into diatomite
PETROLEUM SCIENCE AND TECHNOLOGY
2001; 19 (9-10): 1167-1185
View details for Web of Science ID 000172825800010
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Streamline approach for history matching production data
SPE JOURNAL
2000; 5 (4): 353-362
View details for Web of Science ID 000165780400002
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Spontaneous imbibition characteristics of diatomite
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
2000; 25 (3-4): 149-165
View details for Web of Science ID 000087327000004
- Matrix-Fracture Interactions in Single Matrix Blocks, Twenty-Fifth Workshop on Geothermal Reservoir Engineering 2000
- Transient Foam Flow in Homogeneous Porous Media: Surfactant Concentration and End Effects SPE/DOE Improved Oil Recovery Symposium 2000
- An Experimental Investigation of Permeability and Porosity Alteration in Diatomite During Hot Fluid Injection SPE Western Regional Meeting 2000
- A Streamline Approach for History Matching Production Data SPE 59370 SPE/DOE Improved Oil Recovery Symposium, Tulsa, OK April 3-5 2000
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Foam Flow in Heterogeneous Porous Media: Effect of Cross Flow
SPE JOURNAL
1999; 4 (2): 75-82
View details for Web of Science ID 000209016800001
- Simulation of Early-Time Response of Single- Well Steam Assisted Gravity Drainage SPE Western Regional Meeting 1999
- A Numerical Analysis of the Single-Well Steam Assisted Gravity Drainage 20th Annual International Energy Agency Workshop and Symposium 1999
- Imbibition Studies in Low-Permeability Porous Media SPE Western Regional Meeting 1999
- Foam flow in heterogeneous porous media: Effect of crossflow SPE/DOE Improved Oil Recovery Symposium 1999: 75–82
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Statistical network theory of silica deposition and dissolution in diatomite
IN SITU
1999; 23 (1): 21-53
View details for Web of Science ID 000079297100002
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Effect of mobility ratio on pattern behavior of a homogeneous porous medium
IN SITU
1999; 23 (1): 1-20
View details for Web of Science ID 000079297100001
- Permeability modification of diatomite during hot-fluid injection Journal of Petroleum Technology 1998; 50: 98-100
- Spontaneous water imbibition into diatomite SPE Western Regional Meeting 1998
- Effect of mobility ratio on areal sweep efficiency and pattern flood behavior 19th Annual International Energy Agency Workshop and Symposium 1998
- Foam flow in heterogeneous porous media: Effect of crossflow. SPE 39678 SPE/DOE Improved Oil Recovery Symposium, Tulsa 1998
- Reservoir simulation of foam displacement processes 7th UNITAR International Conference on Heavy Crude and Tar Sands 1998
- Permeability modification of diatomite during hot fluid injection SPE Western Regional Meeting 1998
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Evaluation of rock/fracture interactions during steam injection through vertical hydraulic fractures
1995 SPE Western Regional Meeting
SOC PETROLEUM ENG. 1997: 100–105
View details for Web of Science ID A1997WZ49200007
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Gas bubble snap-off under pressure-driven flow in constricted noncircular capillaries
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
1996; 117 (1-2): 55-76
View details for Web of Science ID A1996VJ28400007
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Interpretation of hydrofracture geometry during steam injection using temperature transients .2. Asymmetric hydrofractures
IN SITU
1996; 20 (3): 289-309
View details for Web of Science ID A1996VD09500003
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Interpretation of hydrofracture geometry during steam injection using temperature transients .1. Model formulation and verification
IN SITU
1996; 20 (3): 251-288
View details for Web of Science ID A1996VD09500002
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Dividing oil fields into regions with similar characteristic behavior using neural network and fuzzy logic approaches
1996 Biennial Conference of the North-American-Fuzzy-Information-Processing-Society
I E E E. 1996: 164–169
View details for Web of Science ID A1996BF95N00032
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A MECHANISTIC POPULATION BALANCE MODEL FOR TRANSIENT AND STEADY-STATE FOAM FLOW IN BOISE SANDSTONE
CHEMICAL ENGINEERING SCIENCE
1995; 50 (23): 3783-3799
View details for Web of Science ID A1995TK32000010
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FOAM FLOW-THROUGH A TRANSPARENT ROUGH-WALLED ROCK FRACTURE
JOURNAL OF PETROLEUM SCIENCE AND ENGINEERING
1995; 13 (2): 75-86
View details for Web of Science ID A1995RF53300001
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FUNDAMENTALS OF FOAM TRANSPORT IN POROUS-MEDIA
FOAMS: FUNDAMENTALS AND APPLICATIONS IN THE PETROLEUM INDUSTRY
1994; 242: 115-163
View details for Web of Science ID A1994BB26W00003
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A PORE-LEVEL SCENARIO FOR THE DEVELOPMENT OF MIXED WETTABILITY IN OIL-RESERVOIRS
AICHE JOURNAL
1993; 39 (6): 1072-1085
View details for Web of Science ID A1993LF90900015