combined modelling and wellbore network meeting

Combined Modelling and Wellbore Network MeetingPerth, 27 – 29 April 2011

In Salah – Reservoir Engineering and then?Bert van der Meer, Senior Reservoir Engineer

10 januari 20111

Outline

• Introduction• In Salah the project• Reservoir Engineering• Geomechanics• Conclusions

10 januari 2011Bert van der Meer, Senior Reservoir Engineer

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InSAR, Observation Tool

Frac, Fault, Permeability

Geomechanics

Publications• Philip Ringrose, first break.• Philip Ringrose, et al., (GHGT-10)• Allan Mathieson, et al., (GHGT-9)• Allan Mathieson, et al., (GHGT-10)• Takumi Onuma, et al., (GHGT-9)• Takumi Onuma, et al., (GHGT-10)• Jonny Rutqvist, ppt presentation

• D. Vasco, LBNL Paper • Sevket Durucan, et al., (GHGT-10)• Martin Iding, et al., (GHGT-9)• R. Bissell, et al., (GHGT-10)• James Smith, et al., (GHGT-10)

• J. Morris, et al., (GHGT-10)• Jonny Rutqvist, et al., (GHGT-9)

CO2ReMoVe Project (Research, Monitoring, Verification)

Monitoring In Salah performance

In Salah CCS (Algeria)

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By: Wright (2006)

In Salah Top Structure

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By: Wright (2006)

Vertical Displacement

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By: Onuma (2008)

Two Models

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By Schlumberger (natural fractured)

KB-5

KB-502

KB-5

KB- 502

By Statoil (fault)

The Schlumberger Model

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•History Matched with estimated BHP from THP.

•Problems with ECLIPSE 300

•Version 2009.2 problems resolved

The Statoil Model

10 januari 2011Bert van der Meer, Senior Reservoir Engineer

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KB-501W-SLB

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KB-503Z-STATOIL

KB-503Z-SLB

e: KB-501W - BHP

c: KB-502Z - BHP

a: KB-503Z - BHP b: KB-503Z – CO2 Inj. Rate

d: KB-502Z – CO2 Inj. Rate

f: KB-501W – CO2 Inj. Rate

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KB-502Z-STATOIL

KB-502Z-SLB

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KB-502Z-SLB

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KB-503Z-STATOIL

KB-503Z-SLB

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KB-503Z-STATOIL

KB-503Z-SLB

e: KB-501W - BHP

c: KB-502Z - BHP

a: KB-503Z - BHP b: KB-503Z – CO2 Inj. Rate

d: KB-502Z – CO2 Inj. Rate

f: KB-501W – CO2 Inj. Rate

1/ Model made larger

2/ History Matched SLB data

3/ history extended

The Statoil HM

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KB-502Z

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KB-502Z (2)

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Conclusions from simulation

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• Well configurations not responsible surface movement humps

• Fault as such not responsible surface movement humps

• Reservoir description not suitable• Engineered permeability distribution not the solution

(Vasco, Durucan)

Against! = Solution Engineering

No geological justification

Geomechanics?

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• 3 problems to solve– Shape (2 humps)– Impact (largest vertical displacement rate)– Not reversible? (vs. KB-501 and KB-503)

• Further considerations:– Amplification mechanism?– Close to gas reservoir (pressure depletion)– Pressure drop after shut-in – Must be reservoir + overburden effects

Est. FBHP vs. Min. Horizontal Stress(σh)

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295σh0

295σh0

σhσh

pf

)()(0 pT hhhh σσσσ Δ+Δ+=

Modeling exercise

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Geomechanical modeling (TNO

semi-analytical model AEsubs)

Surface uplift due to reservoir

pressurization

Surface movement due to fault

pressurization:

depression plus two-lobe uplift

Conclusions and Remaining questions

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Combined pore pressurization and fault pressurization

Initial surface movement too small with used history match + elastic modulus

Non-linearity between surface movement and history-matched reservoir

pressures

Surface movement depression seems too narrow for fracture at reservoir

depth

Pressure drop in well pressure

Conclusions (2)

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If geomechanics no influence on flow properties i.e. de-coupled simulationIs INSAR data a monitoring tool?Better geology needed of reservoir and overburden Geomechanical properties total spaceMore realizations with simulation solutions/tools

Questions?

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