Field scale co-optimisation of CO2 enhanced oil recovery and storage through swag injection using laboratory estimated relative permeabilities

Kamali, Fatemeh and Hussain, Furqan (2016). Field scale co-optimisation of CO2 enhanced oil recovery and storage through swag injection using laboratory estimated relative permeabilities. In: SPE Asia Pacific Oil and Gas Conference and Exhibition. SPE Asia Pacific Oil and Gas Conference and Exhibition, Perth, WA, Australia, (1-15). 25-27 October, 2016. doi:10.2118/182261-MS


Author Kamali, Fatemeh
Hussain, Furqan
Title of paper Field scale co-optimisation of CO2 enhanced oil recovery and storage through swag injection using laboratory estimated relative permeabilities
Conference name SPE Asia Pacific Oil and Gas Conference and Exhibition
Conference location Perth, WA, Australia
Conference dates 25-27 October, 2016
Convener SPE
Proceedings title SPE Asia Pacific Oil and Gas Conference and Exhibition
Place of Publication Richardson, TX, United States
Publisher Society of Petroleum Engineers
Publication Year 2016
Sub-type Fully published paper
DOI 10.2118/182261-MS
Open Access Status Not yet assessed
Start page 1
End page 15
Total pages 15
Collection year 2017
Language eng
Formatted Abstract/Summary
Numerical simulations are widely used to investigate the performance of simultaneous water and gas (SWAG) injection in the field scale. However, they usually use two-phase water and gas relative permeability functions (kr) and one of the existing correlations (e.g., Stone, Baker) to calculate oil relative permeability in a three-phase displacement. Moreover, the same krg is used for all SWAG injections at different miscibility conditions and fraction of gas injected (FGI).

The recent experimental work has shown that gas relative permeability functions in three-phase SWAG are significantly different from the conventionally used two-phase functions. This paper presents a field scale simulation study to investigate the co-optimization of CO2 storage and EOR using experimentally estimated gas relative permeability functions.

A three-dimensional, layered reservoir model initially saturated with oil phase and connate water is used to examine different injection schemes for co-optimizing oil recovery and CO2 storage efficiency. A mixture of hexane and decane (0.65 and 0.35 mole fraction hexane and decane, respectively) is used for the oil phase. Numerical simulations are run at 70°C and three different pressures (1300, 1700 and 2100 psi) to represent immiscible, near-miscible and miscible displacements for the given fluids. A FGI of 0.5 is used for SWAG displacements run at immiscible, near-miscible and miscible displacements. Then the effect of FGI dependent relative permeability on co-optimization of CO2 storage and EOR is investigated in the near-miscible condition for FGI values equal to 0.25, 0.5, 0.75 and 1.0.

The field scale simulation results, run using experimentally estimated three-phase gas relative permeability are compared with the results when two-phase gas relative permeability is used. The numerical simulation results show that oil recovery rate is underestimated if two-phase relative permeability is used. This effect is more prominent in near-miscible and miscible displacements than immiscible. CO2 storage efficiency and therefore co-optimization function is significantly increased when estimated three-phase gas relative permeability functions are used. Therefore, the accurate description of co-optimization of CO2 storage and EOR in SWAG requires laboratory estimated three-phase relative permeability functions.
Q-Index Code EX
Q-Index Status Provisional Code
Institutional Status Non-UQ

 
Versions
Version Filter Type
Citation counts: Google Scholar Search Google Scholar
Created: Mon, 03 Apr 2017, 14:34:10 EST by Fatemeh Kamali on behalf of UQ Energy Initiative