Project CPG EGR Description


geophysicsFigure 1: Conceptual drawing of the reservoir and surface components of the CO2 injection into a high temperature natural gas reservoir for CO2 storage and combined EGR-CPG development.


Coupling Carbon Capture and Storage (CCS) and geothermal energy extraction, using supercritical CO2 (ScCO2) can in principle enable permanent storage of CO2 in (sedimentary basin) geothermal reservoirs while simultaneously extracting heat energy that can be used to generate clean, i.e., CO2-emission-free, baseload or dispatchable power [1,2]. Supercritical CO2 shows better heat “mining” qualities than water, under most conditions, in spite of its lower heat capacity, because of its higher fluid mobility (i.e., lower kinematic viscosity) and higher thermal expansion coefficient [3,4]. Both a high fluid mobility and a larger thermal expansion coefficient of ScCO2 result in a significant thermosiphon effect that reduces or eliminates parasitic pumping power requirements, otherwise needed to circulate and produce fluids in conventional hydrothermal systems [5]. Furthermore, ScCO2 has also been used to enhance oil and gas recovery at partially depleted reservoirs over the last three decades, resulting in increased oil and gas production rates, while simultaneously, partially sequestering CO2 in the oil and gas reservoirs [6,7]. Against the backdrop of strongly fluctuating oil prices, the oil and gas industries are diversifying their business portfolio to include renewable energy options. The use, or conversion of, partially or fully depleted gas reservoirs for CO2 storage and simultaneous co-production of geothermal energy and natural gas is likely to result in several opportunities (Figure 1). Some of these opportunities include: (i) enabling Carbon Capture Utilization and Storage (CCUS); (ii) high fluid (CO2) injectivity can increase the heat energy and natural gas extraction rate from the geothermal natural gas reservoir; (iii) improving the total amount of recoverable natural gas from the reservoir due to reservoir repressurization and/or pressure maintenance; (iv) the existing multidisciplinary datasets, existing surface facilities, and wells can be adapted for CO2 storage and combined EGR-CPG purposes, thus reducing investment costs; (v) increase in the lifetime of the natural gas field and favorable postponement of the cleanup & abandonment stages of the field. This study will focus on the technical assessment and optimization of the combined EGR-CPG application in natural gas reservoirs, while simultaneously storing CO2. The reservoir and surface parameters that could influence CO2 storage and EGR-CPG systems performance, natural gas recovery, and heat mining rates will be studied in detail.


[1] Randolph J.B. and Saar M.O. Coupling carbon dioxide sequestration with geothermal energy capture in naturally permeable, porous geologic formations: Implications for CO2 sequestration, Energy Procedia 2011; 4(1): 2206-13. View on publications page
[2] Zhang L., Ezekiel J., Li D., et al. Potential assessment of CO2 injection for heat mining and geological storage in geothermal reservoirs of China. Appl. Energy 2014; 122: 237-246.View on publications page
[3] Brown D.W. A hot dry rock geothermal energy concept utilizing supercritical CO2 instead of water. Proceedings of the twenty-fifth workshop on geothermal reservoir engineering, Stanford, California, Jan. 24-26, 2000.
[4] Pruess K. Enhanced Geothermal Systems (EGS) comparing water with CO2 as heat transmission fluids. New Zealand Geothermal Workshop 2007, University of Auckland, Auckland, New Zealand. 2007.
[5] Adams B.M., Kuehn T.H., Bielicki J.M., Randolph J.B., Saar M.O. On the importance of the thermosiphon effect in CPG (CO2 plume geothermal) power systems, Energy 2014; 69: 409-418.
[6] Oldenburg C.M., Stevens S.H., Benson S.M. Economic feasibility of carbon sequestration with enhanced gas recovery (CSEGR), Energy 2004; 29:1413–22.
[7] Patel M.J., May, E.F., and Johns M.L. High-fidelity reservoir simulations of enhanced gas recovery with supercritical CO2, Energy 2016; 111(15): 548-59.