Geochemical tracers applied to reservoir simulation of the Weyburn CO2 EOR field

Talman, Stephen; Perkins, Ernie; Jafari, Alireza; Shevalier, Maurice

doi:10.1016/j.ijggc.2013.02.002

Cited by 5 publications

(4 citation statements)

References 12 publications

(19 reference statements)

Supporting

Mentioning

Contrasting

Order By: Relevance

“…16 Modeling based on a single porosity reservoir model failed to reproduce the results from fl uid samples, but a dual porosity model led to better correlations between the results from fi eld samples and modeled parameters. 16 In this study, fl uid and gas samples were collected from observation wells at a CO 2 -EOR pilot project, i.e. straight CO 2 injection, located in central Alberta (Canada) over a fi ve-year period, and analyzed for their chemical and isotopic compositions.…”

Section: Introductionmentioning

confidence: 99%

“…The model and measured values did not correlate well and differences were attributed to water recycling which occurred in the water flood phase prior to CO 2 injection due to ion exchange reactions, calcite dissolution and CO 2 transfer from the oil phase. Another modeling study of the Weyburn CO 2 ‐EOR site using GEM® investigated two species, chloride in the produced water and the carbon isotopic ratio of ethane, δ 13 C‐C 2 H 6 from produced gases . Modeling based on a single porosity reservoir model failed to reproduce the results from fluid samples, but a dual porosity model led to better correlations between the results from field samples and modeled parameters …”

Section: Introductionmentioning

confidence: 99%

“…Another modeling study of the Weyburn CO 2 ‐EOR site using GEM® investigated two species, chloride in the produced water and the carbon isotopic ratio of ethane, δ 13 C‐C 2 H 6 from produced gases . Modeling based on a single porosity reservoir model failed to reproduce the results from fluid samples, but a dual porosity model led to better correlations between the results from field samples and modeled parameters …”

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

A comparison of water chemistry from a CO₂‐enhanced oil recovery project with reactive transport modeling of CO₂ injection into a carbonate reservoir

et al. 2013

View full text Add to dashboard Cite

A long‐term geochemical monitoring program was conducted at a CO2‐enhanced oil recovery site in central Alberta (Canada) to examine geological storage of CO2. The program included geochemical monitoring of reservoir brines, a mineralogical study, and using TOUGHREACT to compare model and field observations. CO2 was injected into a highly permeable carbonate reservoir at 78 tonnes/day for 2.5 years. Fluid and gas samples were obtained for geochemical characterization before, during, and 1.4 years after injection from a production well ∼915 m from the injection well at a depth of ∼936 m. Downhole water compositions were calculated using SOLMINEQ88 and compared to predictions from TOUGHREACT. Following CO2 breakthrough after ∼23 months, downhole pH decreased, HCO3−; and calcium concentrations increased, while magnesium concentrations changed marginally, indicating solubility and ionic trapping were occurring simultaneously. Trends in analyzed and modeled species were similar, but concentration levels were different. Calibrating the model to achieve better correlation between results was attempted but proved unsuccessful. The variances were likely caused by differences between ideal and reservoir mineral's kinetic parameters, surface area, thermodynamic parameters and sampling technique. Five‐hundred‐year simulations showed the CO2 plume migrating vertically due to capillary forces with no significant change in gas saturation below the caprock over the post‐injection period. The majority of CO2 remained trapped as a supercritical phase as the reservoir is composed of only carbonate minerals. The low reactivity of the reservoir is positive, in that the reservoir is not negatively impacted by dissolution and negative in that no mineral trapping occurs. © 2013 Society of Chemical Industry and John Wiley & Sons, Ltd

show abstract

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

A comparison of water chemistry from a CO₂‐enhanced oil recovery project with reactive transport modeling of CO₂ injection into a carbonate reservoir

et al. 2013

View full text Add to dashboard Cite

show abstract

“…Carbon dioxide capture and storage (CCS) is one of the most effective options for CO 2 mitigation and deep saline aquifers hosting the most CO 2 storage potential are considered as one of the preferential choices . Commercial‐scale CO 2 sequestration projects (Sleipner, In Salah, Snøhvit, Weyburn, Ordos) and pilot‐scale CO 2 injection tests (Frio, Nakaoga, Ketzin, BBB‐Nm) indicate that CO 2 sequestration in deep saline aquifers is technically feasible. It could be one of the most important choices for China because an increasing amount of CO 2 emissions continues for the current energy structure, which is dominated by coal (65%∼70%) and fossil fuel…”

Section: Introductionmentioning

confidence: 99%

Hydrogeochemical characteristics of deep saline aquifers in sedimentary basins in China and implications for CO₂ geological storage with emphasis on total dissolved solids (TDS) and water type

Pang

2016

Greenhouse Gases

View full text Add to dashboard Cite

The hydrogeochemistry of deep saline aquifers in sedimentary basins, in particular total dissolved solids, is one of the key criteria for CO2 storage because CO2 solubility is greatly affected by it. A detailed investigation of total dissolved solids (TDS) and water type of formation water is presented in the paper to assess the suitability of sedimentary basins in China for CO2 sequestration. Deep saline aquifers are divided into three categories based on TDS and water type: fresh‐slightly saline water with TDS less than 10 g/L, semi saline–saline water with TDS ranging from 10 g/L to 50 g/L, and salty water with TDS higher than 50 g/L. The fresh, slightly saline water is dominated by water type of Cl·HCO3‐Na in sedimentary basins in East China. Semi saline‐saline and salty waters are of Cl‐Na type existing in the southeast and mid‐west. TDS limits are suggested for different regions of China to optimize the use of formation water. Solubility of CO2 in formation water with TDS of 1g/L∼260g/L is calculated. Results show it exhibits exponential correlation to water TDS and two sharp inflections are observed at 10 g/L and 50 g/L. For fresh‐slightly saline aquifer, TDS limit is defined as 3 g/L in East China while in West China, 5 g/L is suggested. For formation water with TDS of 10 g/L∼150 g/L, 10 g/L is proposed for the main sedimentary basins in China. For deep saline aquifers with TDS higher than 150 g/L, CO2 storage is not suggested to avoid conflicts with salts mineral resources exploration. © 2016 Society of Chemical Industry and John Wiley & Sons, Ltd.

show abstract

Field Observations of Geochemical Response to CO2 Injection at the Reservoir Scale

Hovorka

2019

Science of Carbon Storage in Deep Saline Formations

View full text Add to dashboard Cite

Geochemical tracers applied to reservoir simulation of the Weyburn CO2 EOR field

Cited by 5 publications

References 12 publications

A comparison of water chemistry from a CO₂‐enhanced oil recovery project with reactive transport modeling of CO₂ injection into a carbonate reservoir

A comparison of water chemistry from a CO₂‐enhanced oil recovery project with reactive transport modeling of CO₂ injection into a carbonate reservoir

Hydrogeochemical characteristics of deep saline aquifers in sedimentary basins in China and implications for CO₂ geological storage with emphasis on total dissolved solids (TDS) and water type

Field Observations of Geochemical Response to CO2 Injection at the Reservoir Scale

Contact Info

Product

Resources

About

Geochemical tracers applied to reservoir simulation of the Weyburn CO2 EOR field

Cited by 5 publications

References 12 publications

A comparison of water chemistry from a CO2‐enhanced oil recovery project with reactive transport modeling of CO2 injection into a carbonate reservoir

A comparison of water chemistry from a CO2‐enhanced oil recovery project with reactive transport modeling of CO2 injection into a carbonate reservoir

Hydrogeochemical characteristics of deep saline aquifers in sedimentary basins in China and implications for CO2 geological storage with emphasis on total dissolved solids (TDS) and water type

Field Observations of Geochemical Response to CO2 Injection at the Reservoir Scale

Contact Info

Product

Resources

About

A comparison of water chemistry from a CO₂‐enhanced oil recovery project with reactive transport modeling of CO₂ injection into a carbonate reservoir

A comparison of water chemistry from a CO₂‐enhanced oil recovery project with reactive transport modeling of CO₂ injection into a carbonate reservoir

Hydrogeochemical characteristics of deep saline aquifers in sedimentary basins in China and implications for CO₂ geological storage with emphasis on total dissolved solids (TDS) and water type