Seven (7) Unique Appraisal Challenges Derisking CCS projects or, ‘What Makes This so Different From Oil and Gas?’

Friday, February 23, 2024

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Course Credit: 0.15 CEU, 1.5 PDH

Friday, February 23, 2024 | 09:00AM – 10:30AM CT

Participation in over 150 carbon capture and sequestration (CCS) projects spanning more than 25 years has led to the evolution of a recommended well-based appraisal workflow for CO2 sequestration in saline aquifers. Interpretation methods are expressly adapted for CCS applications to resolve key reservoir parameters, constrain field-scale modeling, provide answers required for the permitting process, and derisk the three principal CCS evaluation challenges: storage capacity, injectivity, and containment. Each of these may be further complicated by eventual three-way interaction between rock matrix, brine, and CO2 streams.

Many relevant logging and core analysis techniques for CCS may be borrowed or adapted from oil and gas exploration and other related industries, but acquiring, interpreting, and putting the data to optimum use requires an entirely new mindset. We highlight seven specific technical challenges of CCS appraisal that make it completely different from, and much more challenging than conventional oil and gas appraisal. For example, in hydrocarbon exploration, petrophysicists have become adept at acquiring and interpreting downhole measurements to quantify existing fluid saturations. In a CCS project, there is no saturation to measure—it doesn’t exist yet, but it is critical to be able to accurately predict its future value. In another example, once a hydrocarbon discovery is made, a good seal is implied. In aquifer CCS projects, the seal has never been put to the test, but is a critical element of the storage complex. In addition to adapted log and log-interpretation techniques, fit-for-purpose developments in laboratory analysis are especially important, and the possible impact of CO2 exposure to key reservoir properties over time must always be considered. This can be investigated via unique SCAL workflows, with results projected decades or centuries into the future via digital SCAL models.

Integration of the results in a dynamic simulation predicting hydraulic, mechanical, chemical, and thermal changes that will be associated with CO2 sequestration provides effective derisking of prospective CCS projects.

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

This webinar is free to SPE Members.

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Course Chapters

1Seven (7) unique appraisal challenges derisking CCS projects or, ‘What makes this so different from oil and gas?'
Media Type: Video
Participation in over 150 carbon capture and sequestration (CCS) projects spanning more than 25 years has led to the evolution of a recommended well-based appraisal workflow for CO2 sequestration in saline aquifers. Interpretation methods are expressly adapted for CCS applications to resolve key reservoir parameters, constrain field-scale modeling, provide answers required for the permitting process, and derisk the three principal CCS evaluation challenges: storage capacity, injectivity, and containment. Each of these may be further complicated by eventual three-way interaction between rock matrix, brine, and CO2 streams. Many relevant logging and core analysis techniques for CCS may be borrowed or adapted from oil and gas exploration and other related industries, but acquiring, interpreting, and putting the data to optimum use requires an entirely new mindset. We highlight seven specific technical challenges of CCS appraisal that make it completely different from, and much more challenging than conventional oil and gas appraisal. For example, in hydrocarbon exploration, petrophysicists have become adept at acquiring and interpreting downhole measurements to quantify existing fluid saturations. In a CCS project, there is no saturation to measure—it doesn’t exist yet, but it is critical to be able to accurately predict its future value. In another example, once a hydrocarbon discovery is made, a good seal is implied. In aquifer CCS projects, the seal has never been put to the test, but is a critical element of the storage complex. In addition to adapted log and log-interpretation techniques, fit-for-purpose developments in laboratory analysis are especially important, and the possible impact of CO2 exposure to key reservoir properties over time must always be considered. This can be investigated via unique SCAL workflows, with results projected decades or centuries into the future via digital SCAL models. Integration of the results in a dynamic simulation predicting hydraulic, mechanical, chemical, and thermal changes that will be associated with CO2 sequestration provides effective derisking of prospective CCS projects. Webinars are FREE to all Members.

Credits

Earn credits by completing this course0.15 CEU credit1.5 PDH credits

Speakers

Robert J. LarongaRobert Laronga graduated Cornell University in 1994 with a B.A. in geology and immediately joined Schlumberger as a Wireline Field Engineer in the Permian Basin. Among varied assignments in the US and internationally, Robert’s career includes seven years of field work, both land and offshore, five years in the capacity of Headquarters Geologist, six years as integrated Team Lead for Unconventionals, and most recently three years as Petrophysics Domain for onshore North America. Amid growing CCS and CCUS activity, he has consulted on over forty CCS and CCUS projects since 2019, helping operators from various industries conduct data acquisition and analysis programs to reduce project risks, assure safe and economic operation, and satisfy regulatory requirements.

Ryan Lemiski- ModeratorSenior GeoscientistRyan Lemiski is a senior geoscientist at Carbon Alpha. He has a Bachelor of Science in Geology (Honors) from the University of Alberta, and a Master of Science, Earth and Atmospheric Sciences from the University of Alberta. He also earned his Master of Earth and Energy Resources Leadership from Queen’s University. Past experiences include domestic and international roles that have focused on conventional and unconventional hydrocarbon exploration and development. In his current role, Ryan conducts rigorous, multidisciplinary, risk-based subsurface workflows that provide the outputs required for decision making during the site screening, selection, and characterization phases of carbon storage project evaluations. Carbon Alpha allows him to use his academic and industry experience to test subsurface concepts and ideas in a rapidly evolving carbon emissions abatement sector.