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Technology Collaboration Programme by IEA

CCP Results – Carbon Dioxide Capture for Storage in Deep Geologic Formations

Other

1 June 2022

Storage

Edited by Karl F Gerdes

Citation: Carbon Dioxide Capture for Storage in Deep Geologic Formations: Results from the CO2 Capture Project - Volume Five: CCS Technology Development and Demonstration Results (2015-2022)

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Overview

CCP has continued to be a leading participant in the response of the oil and gas industry to the challenge of de-carbonizing the energy system. During CCP Phase 4, emerging technologies have been tested and assessed that have great potential to lower the cost of post-combustion capture. A new initiative examined improved ways to deal with CO2 separation and storage for offshore natural gas production. On the CO2 storage side, novel monitoring technologies have been tested and assessed, and mitigation methods to de-risk possible leakage pathways have been field-trialled at the Swiss Mont Terri underground laboratory. All this work is aimed as assuring long-term storage security.

Publication Summary

A few highlights of CCP4 include:

  • Demonstrated in two different pilot campaigns that the Piperazine with Advanced Stripper(PZASTM) capture process has a wide range of application–from NGCC to coal-fired flu gas.
  • Used a series of Techno-Economic Assessments (TEA) to compare innovative capture technologies for NGCC and identified use of Molten Carbonate Fuel Cells (MCFC) as a low-cost option.
  • Supported testing of structured adsorbents with potential for higher productivity (kg CO2/m3hr) and lower pressure drop than conventional packed bed adsorbents. Applications include Sorbent Enhanced Water Gas Shift (SEWGS) to improve economics of low-carbon H2 production and post-combustion capture.
  • Demonstrated Svante’s innovative adsorption-based CO2 capture system at a pilot scale of 1 tonne per day (TPD) at Lafarge Canada’s Richmond cement plant, which has a CO2 concentration similar to SMR flue gas.
  • Supported testing of polymeric membranes for CO2 separation at the harsh conditions necessary to implement subsea wellhead processing and CO2 reinjection as part of the COMPMEM project.
  • Conducted two modelling studies related to storage assurance–one examined operational management of stresses in an EOR reservoir to preserve caprock integrity for subsequent use CO2 storage, and the second looked at the ability to detect leakage associated with a degraded plugged and abandoned well.
  • Completed a study combining modelling with lab experiments assessed the ability of a silica gel agent injected into a storage formation to prevent or mitigate leakage.
  • Compiled a database of the early operating experience of storage projects–ranging from pilots to demonstrations to commercial operation. Lessons learned were extracted from incidents and unanticipated variances between expected and actual performance.
  • Conducted two field experiments at the Mont Terri Underground Laboratory–one to test various injected sealants injected to mitigate leakage in a purposely-damaged well, and the second to examine possible effects of fluid injection on fault slippage with
    implications for fluid leakage.
  • Modelled novel technologies based on the ongoing Aquistore saline storage project to assess surveillance capabilities of (1) time lapse borehole gravity and (2) borehole to surface electromagnetics

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