Interactions of CO2 with formation waters, oil and minerals and CO2 storage at the Weyburn IEA EOR site, Saskatchewan, Canada

Ian Hutcheon, Maurice Shevalier, Kyle Durocher, John Bloch, Gareth Johnson, Michael Nightingale, Bernhard Mayer

Research output: Contribution to journalArticle

9 Citations (Scopus)

Abstract

The Weyburn oil field in Saskatchewan, Canada, is hosted in Mississippian carbonates and has been subject to injection of CO2 since 2000. A detailed mineralogy study was completed as the basis for modeling of mineral storage of injected CO2. Combining the mineralogy with kinetic reaction path models and water chemistry allows estimates of mineral storage of CO2 over 50 years of injection. These results, combined with estimates of pore volume, solubility of CO2 in oil and saline formation waters, and the initial and final pore volume saturation with respect to oil, saline water and gas/supercritical fluid allow an estimate of CO2 stored in saline water, oil and minerals over 50 years of CO2 injection. Most injected CO2 is stored in oil (6.5•106 to 1.3•107 tonnes), followed closely by storage in supercritical CO2 (7.2•106 tonnes) with saline formation water (1.5 - 2•106 tonnes) and mineral storage (2 - 6•105 tonnes) being the smallest sinks. If the mineral dawsonite forms, as modeling suggests, the majority of CO2 dissolved in oil and salineformation water will be redistributed into minerals over a period of approximately 5000 years. The composition of produced fluids from a baseline sampling program, when compared to produced fluids taken three years after injection commenced, suggest that dawsonite is increasingly stable as pH decreases due to CO2 injection. The results suggest that hydrocarbon reservoirs that contain low gravity oil and little or no initial gas saturation prior to CO2 injection, may store the majority of injected CO2 solubilized in oil, making such reservoirs the preferred targets for combined enhanced oil recovery-CO2 storage projects.
LanguageEnglish
Pages354-370
Number of pages17
JournalInternational Journal of Greenhouse Gas Control
Volume53
DOIs
Publication statusPublished - 27 Aug 2016

Fingerprint

formation water
Minerals
oil
mineral
dawsonite
Water
Mineralogy
Saline water
fluid
mineralogy
saturation
enhanced oil recovery
hydrocarbon reservoir
reaction kinetics
Supercritical fluids
Fluids
Oils
gas
water chemistry
water

Keywords

  • co2 storage
  • mineralogy
  • dawsonite
  • geochemical modelling
  • oil water gas rock interactions
  • co2 storage in EOR

Cite this

Hutcheon, Ian ; Shevalier, Maurice ; Durocher, Kyle ; Bloch, John ; Johnson, Gareth ; Nightingale, Michael ; Mayer, Bernhard. / Interactions of CO2 with formation waters, oil and minerals and CO2 storage at the Weyburn IEA EOR site, Saskatchewan, Canada. In: International Journal of Greenhouse Gas Control . 2016 ; Vol. 53. pp. 354-370.
@article{77f138b8d44c432389d9ec4c4dacff39,
title = "Interactions of CO2 with formation waters, oil and minerals and CO2 storage at the Weyburn IEA EOR site, Saskatchewan, Canada",
abstract = "The Weyburn oil field in Saskatchewan, Canada, is hosted in Mississippian carbonates and has been subject to injection of CO2 since 2000. A detailed mineralogy study was completed as the basis for modeling of mineral storage of injected CO2. Combining the mineralogy with kinetic reaction path models and water chemistry allows estimates of mineral storage of CO2 over 50 years of injection. These results, combined with estimates of pore volume, solubility of CO2 in oil and saline formation waters, and the initial and final pore volume saturation with respect to oil, saline water and gas/supercritical fluid allow an estimate of CO2 stored in saline water, oil and minerals over 50 years of CO2 injection. Most injected CO2 is stored in oil (6.5•106 to 1.3•107 tonnes), followed closely by storage in supercritical CO2 (7.2•106 tonnes) with saline formation water (1.5 - 2•106 tonnes) and mineral storage (2 - 6•105 tonnes) being the smallest sinks. If the mineral dawsonite forms, as modeling suggests, the majority of CO2 dissolved in oil and salineformation water will be redistributed into minerals over a period of approximately 5000 years. The composition of produced fluids from a baseline sampling program, when compared to produced fluids taken three years after injection commenced, suggest that dawsonite is increasingly stable as pH decreases due to CO2 injection. The results suggest that hydrocarbon reservoirs that contain low gravity oil and little or no initial gas saturation prior to CO2 injection, may store the majority of injected CO2 solubilized in oil, making such reservoirs the preferred targets for combined enhanced oil recovery-CO2 storage projects.",
keywords = "co2 storage, mineralogy, dawsonite, geochemical modelling, oil water gas rock interactions, co2 storage in EOR",
author = "Ian Hutcheon and Maurice Shevalier and Kyle Durocher and John Bloch and Gareth Johnson and Michael Nightingale and Bernhard Mayer",
year = "2016",
month = "8",
day = "27",
doi = "10.1016/j.ijggc.2016.08.004",
language = "English",
volume = "53",
pages = "354--370",
journal = "International Journal of Greenhouse Gas Control",
issn = "1750-5836",

}

Interactions of CO2 with formation waters, oil and minerals and CO2 storage at the Weyburn IEA EOR site, Saskatchewan, Canada. / Hutcheon, Ian; Shevalier, Maurice; Durocher, Kyle; Bloch, John; Johnson, Gareth; Nightingale, Michael; Mayer, Bernhard.

In: International Journal of Greenhouse Gas Control , Vol. 53, 27.08.2016, p. 354-370.

Research output: Contribution to journalArticle

TY - JOUR

T1 - Interactions of CO2 with formation waters, oil and minerals and CO2 storage at the Weyburn IEA EOR site, Saskatchewan, Canada

AU - Hutcheon, Ian

AU - Shevalier, Maurice

AU - Durocher, Kyle

AU - Bloch, John

AU - Johnson, Gareth

AU - Nightingale, Michael

AU - Mayer, Bernhard

PY - 2016/8/27

Y1 - 2016/8/27

N2 - The Weyburn oil field in Saskatchewan, Canada, is hosted in Mississippian carbonates and has been subject to injection of CO2 since 2000. A detailed mineralogy study was completed as the basis for modeling of mineral storage of injected CO2. Combining the mineralogy with kinetic reaction path models and water chemistry allows estimates of mineral storage of CO2 over 50 years of injection. These results, combined with estimates of pore volume, solubility of CO2 in oil and saline formation waters, and the initial and final pore volume saturation with respect to oil, saline water and gas/supercritical fluid allow an estimate of CO2 stored in saline water, oil and minerals over 50 years of CO2 injection. Most injected CO2 is stored in oil (6.5•106 to 1.3•107 tonnes), followed closely by storage in supercritical CO2 (7.2•106 tonnes) with saline formation water (1.5 - 2•106 tonnes) and mineral storage (2 - 6•105 tonnes) being the smallest sinks. If the mineral dawsonite forms, as modeling suggests, the majority of CO2 dissolved in oil and salineformation water will be redistributed into minerals over a period of approximately 5000 years. The composition of produced fluids from a baseline sampling program, when compared to produced fluids taken three years after injection commenced, suggest that dawsonite is increasingly stable as pH decreases due to CO2 injection. The results suggest that hydrocarbon reservoirs that contain low gravity oil and little or no initial gas saturation prior to CO2 injection, may store the majority of injected CO2 solubilized in oil, making such reservoirs the preferred targets for combined enhanced oil recovery-CO2 storage projects.

AB - The Weyburn oil field in Saskatchewan, Canada, is hosted in Mississippian carbonates and has been subject to injection of CO2 since 2000. A detailed mineralogy study was completed as the basis for modeling of mineral storage of injected CO2. Combining the mineralogy with kinetic reaction path models and water chemistry allows estimates of mineral storage of CO2 over 50 years of injection. These results, combined with estimates of pore volume, solubility of CO2 in oil and saline formation waters, and the initial and final pore volume saturation with respect to oil, saline water and gas/supercritical fluid allow an estimate of CO2 stored in saline water, oil and minerals over 50 years of CO2 injection. Most injected CO2 is stored in oil (6.5•106 to 1.3•107 tonnes), followed closely by storage in supercritical CO2 (7.2•106 tonnes) with saline formation water (1.5 - 2•106 tonnes) and mineral storage (2 - 6•105 tonnes) being the smallest sinks. If the mineral dawsonite forms, as modeling suggests, the majority of CO2 dissolved in oil and salineformation water will be redistributed into minerals over a period of approximately 5000 years. The composition of produced fluids from a baseline sampling program, when compared to produced fluids taken three years after injection commenced, suggest that dawsonite is increasingly stable as pH decreases due to CO2 injection. The results suggest that hydrocarbon reservoirs that contain low gravity oil and little or no initial gas saturation prior to CO2 injection, may store the majority of injected CO2 solubilized in oil, making such reservoirs the preferred targets for combined enhanced oil recovery-CO2 storage projects.

KW - co2 storage

KW - mineralogy

KW - dawsonite

KW - geochemical modelling

KW - oil water gas rock interactions

KW - co2 storage in EOR

U2 - 10.1016/j.ijggc.2016.08.004

DO - 10.1016/j.ijggc.2016.08.004

M3 - Article

VL - 53

SP - 354

EP - 370

JO - International Journal of Greenhouse Gas Control

T2 - International Journal of Greenhouse Gas Control

JF - International Journal of Greenhouse Gas Control

SN - 1750-5836

ER -