Pore Network Analysis of Brae Formation Sandstone, North Sea. / Thomson, Paul-Ross; Jefferd, Mark; Clark, Brett; Chiarella, Domenico; Mitchell, Tom; Hier-Majumder, Saswata.

In: Marine and Petroleum Geology, Vol. 122, 104614, 12.2020.

Research output: Contribution to journalArticlepeer-review

Published

Standard

Pore Network Analysis of Brae Formation Sandstone, North Sea. / Thomson, Paul-Ross; Jefferd, Mark; Clark, Brett; Chiarella, Domenico; Mitchell, Tom; Hier-Majumder, Saswata.

In: Marine and Petroleum Geology, Vol. 122, 104614, 12.2020.

Research output: Contribution to journalArticlepeer-review

Harvard

APA

Vancouver

Author

Thomson, Paul-Ross ; Jefferd, Mark ; Clark, Brett ; Chiarella, Domenico ; Mitchell, Tom ; Hier-Majumder, Saswata. / Pore Network Analysis of Brae Formation Sandstone, North Sea. In: Marine and Petroleum Geology. 2020 ; Vol. 122.

BibTeX

@article{0bec4df9d401464d98e9f52722322c8f,
title = "Pore Network Analysis of Brae Formation Sandstone, North Sea",
abstract = "In this work, we apply digital rock physics (DRP) to characterize the pore networks of the Brae Formation sandstones from two different wells in the Miller field area (North Sea, UK). Using X-ray micro-CT scans, we calculate the porosity and permeability and generate pore network models to assess pore shape characteristics. The porous samples are marked by macroporosities ranging from 4.9% to 15.2% with the effective porosities varying from 0 to 14.8%. The samples also contained some microporosity hosted in secondary and accessory mineral phases, varying between 2.6% to 10.7%. Pore network model results for total porosity indicate that the samples have median pore and throat radii ranging from 5.5 µm to 16.8 µm and 6.4 µm to 12.9 µm, respectively. The throat length of all samples has a median value ranging between 36.3 µm and 82.4 µm. The ratio between effective porosity and total porosity ($\phi^\ast$) varies with total porosity ($\phi$) following the exponential relation φ* = 0.98 - e^{-(φi-0.032)/0.028}. Pore network connectivity is established at a porosity of 3% and full communication is achieved at porosities exceeding 10%. Permeability was found to vary with total porosity with an exponent of 3.67. Based on these observations and the results from our models, the connectivity of the pore network has important implications for predicting reservoir performance during large scale subsurface projects such as hydrocarbon production and CO2 storage.",
author = "Paul-Ross Thomson and Mark Jefferd and Brett Clark and Domenico Chiarella and Tom Mitchell and Saswata Hier-Majumder",
year = "2020",
month = dec,
doi = "10.1016/j.marpetgeo.2020.104614",
language = "English",
volume = "122",
journal = "Marine and Petroleum Geology",
issn = "0264-8172",
publisher = "Elsevier BV",

}

RIS

TY - JOUR

T1 - Pore Network Analysis of Brae Formation Sandstone, North Sea

AU - Thomson, Paul-Ross

AU - Jefferd, Mark

AU - Clark, Brett

AU - Chiarella, Domenico

AU - Mitchell, Tom

AU - Hier-Majumder, Saswata

PY - 2020/12

Y1 - 2020/12

N2 - In this work, we apply digital rock physics (DRP) to characterize the pore networks of the Brae Formation sandstones from two different wells in the Miller field area (North Sea, UK). Using X-ray micro-CT scans, we calculate the porosity and permeability and generate pore network models to assess pore shape characteristics. The porous samples are marked by macroporosities ranging from 4.9% to 15.2% with the effective porosities varying from 0 to 14.8%. The samples also contained some microporosity hosted in secondary and accessory mineral phases, varying between 2.6% to 10.7%. Pore network model results for total porosity indicate that the samples have median pore and throat radii ranging from 5.5 µm to 16.8 µm and 6.4 µm to 12.9 µm, respectively. The throat length of all samples has a median value ranging between 36.3 µm and 82.4 µm. The ratio between effective porosity and total porosity ($\phi^\ast$) varies with total porosity ($\phi$) following the exponential relation φ* = 0.98 - e^{-(φi-0.032)/0.028}. Pore network connectivity is established at a porosity of 3% and full communication is achieved at porosities exceeding 10%. Permeability was found to vary with total porosity with an exponent of 3.67. Based on these observations and the results from our models, the connectivity of the pore network has important implications for predicting reservoir performance during large scale subsurface projects such as hydrocarbon production and CO2 storage.

AB - In this work, we apply digital rock physics (DRP) to characterize the pore networks of the Brae Formation sandstones from two different wells in the Miller field area (North Sea, UK). Using X-ray micro-CT scans, we calculate the porosity and permeability and generate pore network models to assess pore shape characteristics. The porous samples are marked by macroporosities ranging from 4.9% to 15.2% with the effective porosities varying from 0 to 14.8%. The samples also contained some microporosity hosted in secondary and accessory mineral phases, varying between 2.6% to 10.7%. Pore network model results for total porosity indicate that the samples have median pore and throat radii ranging from 5.5 µm to 16.8 µm and 6.4 µm to 12.9 µm, respectively. The throat length of all samples has a median value ranging between 36.3 µm and 82.4 µm. The ratio between effective porosity and total porosity ($\phi^\ast$) varies with total porosity ($\phi$) following the exponential relation φ* = 0.98 - e^{-(φi-0.032)/0.028}. Pore network connectivity is established at a porosity of 3% and full communication is achieved at porosities exceeding 10%. Permeability was found to vary with total porosity with an exponent of 3.67. Based on these observations and the results from our models, the connectivity of the pore network has important implications for predicting reservoir performance during large scale subsurface projects such as hydrocarbon production and CO2 storage.

U2 - 10.1016/j.marpetgeo.2020.104614

DO - 10.1016/j.marpetgeo.2020.104614

M3 - Article

VL - 122

JO - Marine and Petroleum Geology

JF - Marine and Petroleum Geology

SN - 0264-8172

M1 - 104614

ER -