### Abstract

Synthetic well tests have been produced using a 3D model of an outcropping turbidite sandstone unit from the Cingöz region in southern Turkey. The model contains realistic sand sheet, tongue, lobe and background sand facies architecture (i.e. geometry and stacking) mapped from an outcrop study. The geometric information is useful as an analogue for high net-to-gross turbidite oil fields. The facies have been assigned petrophysical properties from a subsurface analogue. There is little shale in this system. Well test responses were then derived from the high net-to-gross turbidite model using various architectural, porosity-permeability scenarios and completion strategies. The impact on well test derivatives of various sand body geometrics and permeability contrasts could then be determined. Two completion strategies - partial penetration and fully perforated intervals - were assessed for their applicability in the high net-to-gross system. The geological model is effectively a sandbox, and shows a very uniform testing responce from the rather uniform property distributions. However, when the level of permeability heterogeneity is increased by populating the model with varying contrasts of permeability and porosity, the sand body geometry can be seen to influence the well tests. Partial completions in sand bodies are particularly effective in detecting sand body geometry. The geometry controls the flow regimes in a well test response despite variations in the permeability contrasts. The effect of varying geometry is illustrated and an external linear flow regime is identified. Where there is sufficient sand body thickness, partial perforation results in spherical flow, from which a vertical permeability can be obtained. In the model, the vertical permeability thus obtained is a local (to the volume investigated) effective permeability of stacked isotropic facies. This work was undertaken to give guidance on the description of hydrocarbon reservoirs by well testing. If well testing is to be used in high net-to-gross turbidite systems for the purposes of reservoir characterization, then partial perforation of the system should be planned. Interpreted vertical permeabilities should be applied with careful consideration of the stacked pattern of sand bodies.

Original language | English |
---|---|

Pages (from-to) | 19-30 |

Number of pages | 12 |

Journal | Petroleum Geoscience |

Volume | 8 |

Issue number | 1 |

Publication status | Published - 2002 |

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### Keywords

- Outcrop
- Reservoir study
- Simulation
- Turbidite
- Well testing

### Cite this

*Petroleum Geoscience*,

*8*(1), 19-30.

}

*Petroleum Geoscience*, vol. 8, no. 1, pp. 19-30.

**Synthetic well test modelling in a high net-to-gross outcrop system for turbidite reservoir description.** / Robertson, Ewan; Corbett, P. W M; Hurst, Andrew; Satur, Nick; Cronin, Bryan T.

Research output: Contribution to journal › Article

TY - JOUR

T1 - Synthetic well test modelling in a high net-to-gross outcrop system for turbidite reservoir description

AU - Robertson, Ewan

AU - Corbett, P. W M

AU - Hurst, Andrew

AU - Satur, Nick

AU - Cronin, Bryan T.

PY - 2002

Y1 - 2002

N2 - Synthetic well tests have been produced using a 3D model of an outcropping turbidite sandstone unit from the Cingöz region in southern Turkey. The model contains realistic sand sheet, tongue, lobe and background sand facies architecture (i.e. geometry and stacking) mapped from an outcrop study. The geometric information is useful as an analogue for high net-to-gross turbidite oil fields. The facies have been assigned petrophysical properties from a subsurface analogue. There is little shale in this system. Well test responses were then derived from the high net-to-gross turbidite model using various architectural, porosity-permeability scenarios and completion strategies. The impact on well test derivatives of various sand body geometrics and permeability contrasts could then be determined. Two completion strategies - partial penetration and fully perforated intervals - were assessed for their applicability in the high net-to-gross system. The geological model is effectively a sandbox, and shows a very uniform testing responce from the rather uniform property distributions. However, when the level of permeability heterogeneity is increased by populating the model with varying contrasts of permeability and porosity, the sand body geometry can be seen to influence the well tests. Partial completions in sand bodies are particularly effective in detecting sand body geometry. The geometry controls the flow regimes in a well test response despite variations in the permeability contrasts. The effect of varying geometry is illustrated and an external linear flow regime is identified. Where there is sufficient sand body thickness, partial perforation results in spherical flow, from which a vertical permeability can be obtained. In the model, the vertical permeability thus obtained is a local (to the volume investigated) effective permeability of stacked isotropic facies. This work was undertaken to give guidance on the description of hydrocarbon reservoirs by well testing. If well testing is to be used in high net-to-gross turbidite systems for the purposes of reservoir characterization, then partial perforation of the system should be planned. Interpreted vertical permeabilities should be applied with careful consideration of the stacked pattern of sand bodies.

AB - Synthetic well tests have been produced using a 3D model of an outcropping turbidite sandstone unit from the Cingöz region in southern Turkey. The model contains realistic sand sheet, tongue, lobe and background sand facies architecture (i.e. geometry and stacking) mapped from an outcrop study. The geometric information is useful as an analogue for high net-to-gross turbidite oil fields. The facies have been assigned petrophysical properties from a subsurface analogue. There is little shale in this system. Well test responses were then derived from the high net-to-gross turbidite model using various architectural, porosity-permeability scenarios and completion strategies. The impact on well test derivatives of various sand body geometrics and permeability contrasts could then be determined. Two completion strategies - partial penetration and fully perforated intervals - were assessed for their applicability in the high net-to-gross system. The geological model is effectively a sandbox, and shows a very uniform testing responce from the rather uniform property distributions. However, when the level of permeability heterogeneity is increased by populating the model with varying contrasts of permeability and porosity, the sand body geometry can be seen to influence the well tests. Partial completions in sand bodies are particularly effective in detecting sand body geometry. The geometry controls the flow regimes in a well test response despite variations in the permeability contrasts. The effect of varying geometry is illustrated and an external linear flow regime is identified. Where there is sufficient sand body thickness, partial perforation results in spherical flow, from which a vertical permeability can be obtained. In the model, the vertical permeability thus obtained is a local (to the volume investigated) effective permeability of stacked isotropic facies. This work was undertaken to give guidance on the description of hydrocarbon reservoirs by well testing. If well testing is to be used in high net-to-gross turbidite systems for the purposes of reservoir characterization, then partial perforation of the system should be planned. Interpreted vertical permeabilities should be applied with careful consideration of the stacked pattern of sand bodies.

KW - Outcrop

KW - Reservoir study

KW - Simulation

KW - Turbidite

KW - Well testing

UR - http://www.scopus.com/inward/record.url?scp=0036198215&partnerID=8YFLogxK

M3 - Article

VL - 8

SP - 19

EP - 30

JO - Petroleum Geoscience

JF - Petroleum Geoscience

SN - 1354-0793

IS - 1

ER -