An integrated workflow for fracture characterization in chalk reservoirs, applied to the Kraka Field

Tala Maria Aabø*, Jesper Sören Dramsch, Camilla Louise Würtzen, Solomon Seyum, Michael Welch

*Corresponding author for this work

Research output: Contribution to journalJournal articleResearchpeer-review

Abstract

Oil and gas production of tight chalk reservoirs frequently rely on the presence of natural fractures, which increases the effective permeability of the reservoirs. Fracture characterization is therefore imperative in optimizing production schemes and obtaining economically viable recovery factors. Subsurface fracture characterization is often deemed challenging as the available data is typically of varying age and quality, and represents different scales. We have developed an integrated workflow for fracture characterization in chalk to address these challenges. The workflow is based on data from borehole images, cores and seismic. These data are typically available for most chalk (and hydrocarbon) fields. The interpreted borehole image dataset contains over 17 000 manual dip picks, ensuring a statistically viable base. A total of 150 m of core is available from 3 wells. The applied 3D seismic cube covers a 8 × 5 km hydrocarbon chalk field in the Danish North Sea.
In this workflow, the scale-gap between the data sets is bridged by the introduction of two ant-tracked attribute volumes, which display structural trends below the resolution of amplitude seismic. Further insight into the intricacy of subsurface fracture systems is obtained from fracture density logs, which provide an opportunity to study spatial distribution of fractures as well as a qualitative measure of fracture clustering. Cumulative density distribution plots and calculation of the variation coefficient of fracture spacing provide a more quantitative analysis of the fracture distribution.
The workflow, presented here in a step-by-step manner, is a general approach applied to data from the Kraka Field of the Danish North Sea. In the Kraka Field, the usage of this integrated approach shows that the fracture pattern in this region is more complex than previously suggested; probably controlled by the regional maximum horizontal stress and salt movements.
Original languageEnglish
Article number104065
JournalMarine and Petroleum Geology
Volume112
Number of pages12
ISSN0264-8172
DOIs
Publication statusPublished - 2020

Keywords

  • Reservoir characterization
  • Fractures
  • Structural correlation
  • Borehole images
  • Core analysis
  • Seismic attribute volumes
  • Ant-tracking
  • Chalk

Cite this

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title = "An integrated workflow for fracture characterization in chalk reservoirs, applied to the Kraka Field",
abstract = "Oil and gas production of tight chalk reservoirs frequently rely on the presence of natural fractures, which increases the effective permeability of the reservoirs. Fracture characterization is therefore imperative in optimizing production schemes and obtaining economically viable recovery factors. Subsurface fracture characterization is often deemed challenging as the available data is typically of varying age and quality, and represents different scales. We have developed an integrated workflow for fracture characterization in chalk to address these challenges. The workflow is based on data from borehole images, cores and seismic. These data are typically available for most chalk (and hydrocarbon) fields. The interpreted borehole image dataset contains over 17 000 manual dip picks, ensuring a statistically viable base. A total of 150 m of core is available from 3 wells. The applied 3D seismic cube covers a 8 × 5 km hydrocarbon chalk field in the Danish North Sea. In this workflow, the scale-gap between the data sets is bridged by the introduction of two ant-tracked attribute volumes, which display structural trends below the resolution of amplitude seismic. Further insight into the intricacy of subsurface fracture systems is obtained from fracture density logs, which provide an opportunity to study spatial distribution of fractures as well as a qualitative measure of fracture clustering. Cumulative density distribution plots and calculation of the variation coefficient of fracture spacing provide a more quantitative analysis of the fracture distribution.The workflow, presented here in a step-by-step manner, is a general approach applied to data from the Kraka Field of the Danish North Sea. In the Kraka Field, the usage of this integrated approach shows that the fracture pattern in this region is more complex than previously suggested; probably controlled by the regional maximum horizontal stress and salt movements.",
keywords = "Reservoir characterization, Fractures, Structural correlation, Borehole images, Core analysis, Seismic attribute volumes, Ant-tracking, Chalk",
author = "{Maria Aab{\o}}, Tala and {S{\"o}ren Dramsch}, Jesper and W{\"u}rtzen, {Camilla Louise} and Solomon Seyum and Michael Welch",
year = "2020",
doi = "10.1016/j.marpetgeo.2019.104065",
language = "English",
volume = "112",
journal = "Marine and Petroleum Geology",
issn = "0264-8172",
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}

An integrated workflow for fracture characterization in chalk reservoirs, applied to the Kraka Field. / Maria Aabø, Tala; Sören Dramsch, Jesper; Würtzen, Camilla Louise; Seyum, Solomon; Welch, Michael.

In: Marine and Petroleum Geology, Vol. 112, 104065, 2020.

Research output: Contribution to journalJournal articleResearchpeer-review

TY - JOUR

T1 - An integrated workflow for fracture characterization in chalk reservoirs, applied to the Kraka Field

AU - Maria Aabø, Tala

AU - Sören Dramsch, Jesper

AU - Würtzen, Camilla Louise

AU - Seyum, Solomon

AU - Welch, Michael

PY - 2020

Y1 - 2020

N2 - Oil and gas production of tight chalk reservoirs frequently rely on the presence of natural fractures, which increases the effective permeability of the reservoirs. Fracture characterization is therefore imperative in optimizing production schemes and obtaining economically viable recovery factors. Subsurface fracture characterization is often deemed challenging as the available data is typically of varying age and quality, and represents different scales. We have developed an integrated workflow for fracture characterization in chalk to address these challenges. The workflow is based on data from borehole images, cores and seismic. These data are typically available for most chalk (and hydrocarbon) fields. The interpreted borehole image dataset contains over 17 000 manual dip picks, ensuring a statistically viable base. A total of 150 m of core is available from 3 wells. The applied 3D seismic cube covers a 8 × 5 km hydrocarbon chalk field in the Danish North Sea. In this workflow, the scale-gap between the data sets is bridged by the introduction of two ant-tracked attribute volumes, which display structural trends below the resolution of amplitude seismic. Further insight into the intricacy of subsurface fracture systems is obtained from fracture density logs, which provide an opportunity to study spatial distribution of fractures as well as a qualitative measure of fracture clustering. Cumulative density distribution plots and calculation of the variation coefficient of fracture spacing provide a more quantitative analysis of the fracture distribution.The workflow, presented here in a step-by-step manner, is a general approach applied to data from the Kraka Field of the Danish North Sea. In the Kraka Field, the usage of this integrated approach shows that the fracture pattern in this region is more complex than previously suggested; probably controlled by the regional maximum horizontal stress and salt movements.

AB - Oil and gas production of tight chalk reservoirs frequently rely on the presence of natural fractures, which increases the effective permeability of the reservoirs. Fracture characterization is therefore imperative in optimizing production schemes and obtaining economically viable recovery factors. Subsurface fracture characterization is often deemed challenging as the available data is typically of varying age and quality, and represents different scales. We have developed an integrated workflow for fracture characterization in chalk to address these challenges. The workflow is based on data from borehole images, cores and seismic. These data are typically available for most chalk (and hydrocarbon) fields. The interpreted borehole image dataset contains over 17 000 manual dip picks, ensuring a statistically viable base. A total of 150 m of core is available from 3 wells. The applied 3D seismic cube covers a 8 × 5 km hydrocarbon chalk field in the Danish North Sea. In this workflow, the scale-gap between the data sets is bridged by the introduction of two ant-tracked attribute volumes, which display structural trends below the resolution of amplitude seismic. Further insight into the intricacy of subsurface fracture systems is obtained from fracture density logs, which provide an opportunity to study spatial distribution of fractures as well as a qualitative measure of fracture clustering. Cumulative density distribution plots and calculation of the variation coefficient of fracture spacing provide a more quantitative analysis of the fracture distribution.The workflow, presented here in a step-by-step manner, is a general approach applied to data from the Kraka Field of the Danish North Sea. In the Kraka Field, the usage of this integrated approach shows that the fracture pattern in this region is more complex than previously suggested; probably controlled by the regional maximum horizontal stress and salt movements.

KW - Reservoir characterization

KW - Fractures

KW - Structural correlation

KW - Borehole images

KW - Core analysis

KW - Seismic attribute volumes

KW - Ant-tracking

KW - Chalk

U2 - 10.1016/j.marpetgeo.2019.104065

DO - 10.1016/j.marpetgeo.2019.104065

M3 - Journal article

VL - 112

JO - Marine and Petroleum Geology

JF - Marine and Petroleum Geology

SN - 0264-8172

M1 - 104065

ER -