Session 21. Oral Presentation for: Modelling CO2 storage in oil and gas reservoirs in the Gippsland Basin
Dan Gillam AA
Dan Gillam attained a PhD from Adelaide University in 2005, and a Bachelor of Applied Science (hons) from Queensland University of Technology in 1999. Dan joined Esso in Melbourne in 2017 and is currently the subsurface lead for the Southeast Australia Carbon Capture and Storage hub (SEA CCS). Previously working PNG exploration designing fold belt seismic programs and maturing high impact prospects. Prior to Esso, Dan worked for InterOil in Singapore from 2014 to 2017 on the appraisal and certification of the giant Elk Antelope discovery. From 2010 to 2014 Dan worked for Chevron in Perth on the appraisal of deep water discoveries and on the Gorgon CO2 project. From 2005 to 2010 he worked for Woodside Petroleum in a variety of roles across the E&P lifecycle on projects in Australia and Africa. Dan has also worked for Santos on a variety of unconventional projects before and during his PhD. |
Abstract
Presented on Wednesday 22 May: Session 21
The Gippsland Basin has world class geology for carbon capture and storage (CCS) and a long history of oil and gas production. Depleted oil and gas fields within the Gippsland Basin that are candidates for carbon dioxide (CO2) storage are in close proximity to existing infrastructure that could be repurposed as part of a CCS project. Modelling of CO2 storage in the depleted Bream oil and gas reservoir is being progressed. Bream reservoir properties are very well understood due to extensive geological and geophysical data sets available from wells and seismic data. Additionally, the field has been through three key phases of development during its production history; oil production and gas re-injection in 1988, gas cap blowdown started in 2002, and seasonal gas storage and withdrawal started in 2012 through to field shut-in in 2020. This provides a wealth of dynamic data that is used to calibrate the reservoir models to improve our confidence in the CO2 plume prediction. However, there are also challenges in modelling CO2 storage in depleted fields. Unlike saline aquifers, CO2 can be injected into a three-phase depleted reservoir that contains residual oil and gas saturation. The key aspects of our workflow to evaluate the plume behaviour are presented in this paper.
To access the Oral Presentation click the link on the right. To read the full paper click here
Keywords: Bream, CCS, CO2 injection, CO2 plume prediction, decarbonisation, depleted reservoir, Gippsland, residual oil and gas.
Dan Gillam attained a PhD from Adelaide University in 2005, and a Bachelor of Applied Science (hons) from Queensland University of Technology in 1999. Dan joined Esso in Melbourne in 2017 and is currently the subsurface lead for the Southeast Australia Carbon Capture and Storage hub (SEA CCS). Previously working PNG exploration designing fold belt seismic programs and maturing high impact prospects. Prior to Esso, Dan worked for InterOil in Singapore from 2014 to 2017 on the appraisal and certification of the giant Elk Antelope discovery. From 2010 to 2014 Dan worked for Chevron in Perth on the appraisal of deep water discoveries and on the Gorgon CO2 project. From 2005 to 2010 he worked for Woodside Petroleum in a variety of roles across the E&P lifecycle on projects in Australia and Africa. Dan has also worked for Santos on a variety of unconventional projects before and during his PhD. |
