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018 FlexWell-CMOST VO AK


Overview

Introduction

Well Design for SAGD Processes with FlexWell and CMOST
Viera Oballa and Anjani Kumar CMG

Model Description Application Optimization

with CMOST Summary

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Introduction
Why do we need a new Wellbore Model?
Correct handling of:
Wellbore fluid and heat flow

Introduction
Wellbore Models categories
Thermal vs. Isothermal Coupled vs. Stand alone Friction pressure drop calculation
Homogeneous flow – no slip Simple 2 phase with a slip (Drift Flux, Dukler-Bankoff) Flow Regime

transient flow fluid segregation accurate radial conductive heat transfer
Reservoir-wellbore interaction

cross-flow Solid deposition Realistic trajectories Multiple tubing strings Reasonable numerical performance

Steady state vs. Transient
Fluid flow (segregation) Radial and Axial Heat flow

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Model Description
Flexible Wellbore is a collection of tubing strings in an annular space
Multiple directions Independent grid Fully coupled to a reservoir Reservoir solution lags 1 iteration Solid deposition by reaction

Model Description

Solved independently
mechanistic model used to calculate friction pressure drop overall heat transfer coefficient – radial heat flow mass and energy conservation equations

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Model Description
Sink/Source Gravity Friction-heatloss Cross flow W-R Trajectory Multilaterals Transients Fluid segregation Wellbore Heatloss and friction, wellhead to pay top ICD - Orifice flow A-R ICD - Orifice flow T-A Well plugging by solids Tubing Explicit head optional Optional (very simple) optional optional No No optional optional No No No Flex Well implicit automatic automatic optional optional automatic automatic optional optional optional optional Max 3
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Model Description
Tubing(s)
Varying length and/or diameter Partial or full insulation Fluid discharge
Toe Any perforation along the length

Communicate through annulus

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Model Description

Application
Essential to all processes where wellbore behavior and wellbore-reservoir interaction are important Chosen example is a SAGD process
Complex reservoir geology with low perm zones Undulating wellbore
Injector – 3” ID tubing, 705 m long Producer – 3” ID long tubing; 4” ID short tubing

Annulus
Varying length and/or diameter Casing Cement Communicates with a reservoir and each tubing

Operating conditions
Injector – 4000 KPa, 350 m3/day – tubing; annulus - shutin Producer – 3500 kPa, 500m3/day, 5C – both tubings; annulus - shutin

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Application
TUBING - ICD
1.20e+5

Application
Results Analysis
Producer operates mostly on BHP Injector operates on BHP only

1.00e+5

Cumulative Oil SC (m3)

8.00e+4

6.00e+4

How to increase oil production?
Focus on Injector – increase steam injection
Use wider tubing Use multiple tubing strings and/or annulus injection

4.00e+4

2.00e+4

0.00e+0 2009 2010 2011 2012 2013 2014 2015 2016

Time (Date)

Use Inflow Control Device (ICD)

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Application
TUBING - ICD

Application
TUBING - ICD
2.00e+5

2.00e+5

1.50e+5

1.50e+5

Cumulative Oil SC (m3)
2009 2010 2011 2012 2013 2014 2015 2016

Cumulative Oil SC (m3)

1.00e+5

1.00e+5

5.00e+4

5.00e+4

0.00e+0

0.00e+0 2009 2010 2011 2012 2013 2014 2015 2016

Time (Date)
No ICD ICD - 225 m from heel, 54/46 split

Time (Date)
No ICD ICD - 225 m from heel, 54/46 split ICD - 225 m from heel, 67/33 split

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Application
TUBING - ICD
400

Application
Blue Cyan Red 200oC 230oC 240oC

300

Water Rate SC (m3/day)

200

100

0 2009 2010 2011 2012 2013 2014 2015 2016

Time (Date)
No ICD ICD - 225 m from heel, 54/46 split ICD - 225 m from heel, 67/33 split

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Single Well SAGD Model

Well Design for SAGD Processes with FlexWell and CMOST

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Reservoir Property Distributions
Permeability

Well Configuration – Circulation Phase

Water Saturation

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Well Configuration – SAGD Phase

Where to Land the Short and Long Tubing?
Permeability

Injection well

Production well

Low perm zones

Top and Bottom Mobile Water Zones

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Reservoir Heterogeneity

Tubular Configurations: Base Case
Water Saturation

Long Tubing 700 m Long

Short Tubing 50 m Long
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Optimization Parameters
Injection & Production Tubing Lengths

Optimization Results - Case 1
CMOST Optimization based on NPV

NPV up from 16.3M$ to 20.7M$ over 8 years

NPV (M$)

27% Increase in NPV

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Job ID Number

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Wellbore Optimization for SAGD

Optimized Configuration – Tubulars
Optimized Case (# 216) had NPV = 20.673M$ 2nd best optimized Case (# 176) had NPV = 20.343M$
#216 #176

Total number of runs : 229 Total compute time: 7.4 days Total Man days: 3 days Number of simultaneous runs: 10 Hardware:
Westmere - Dual Six Core processor, X5680,3.33GHz,12M,6.4GT/s - 48GB Memory
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Optimization Configuration – Tubulars (#176)

Optimization Configuration – Tubulars (#216)

SHORT TUBING- INJECTION WELL

LONG TUBING-INJECTION WELL

SHORT TUBING- INJECTION WELL

LONG TUBING-INJECTION WELL

SHORT TUBING- PRODUCTION WELL

SHORT TUBING- PRODUCTION WELL

LONG TUBING- PRODUCTION WELL

LONG TUBING- PRODUCTION WELL

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Base Case vs. Optimized Case

Optimization Parameters - Case 2
- Tubular length as per case 1 - Steam Injection Rates (allowed to change every 2 years)

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CMOST Optimization Results

Wellbore and Operating Strategy Optimization for SAGD

NPV up from 16.3M$ to 26.15M$ over 8 yrs

Total number of runs : 633 Total compute time: 21.6 days

NPV (M$)

Total Man days: 1 day Number of simultaneous jobs: 10 Hardware:
60% Increase in NPV

Westmere- Dual Six Core processor, X5680,3.33GHz,12M,6.4GT/s - 48GB Memory
Job ID Number
33 34

Optimization Results – Tubulars
Highest NPV ($26.15m) optimized Run (#504) had:

Optimization Results – Cum. Oil Produced

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Optimization Results – Injection Rates

Steam Chamber Growth

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Steam Chamber Growth
Base Case Optimized Case

Summary
Flexible Wellbore
Can handle wide range processes Models complex wellbore flow Models correctly reservoir-wellbore interaction

CMOST optimization
Well completions and operating strategy can be optimized using CMOST

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TUBING - ICD
3.00e+5 400

TUBING - ICD

300

Cumulative Oil SC (m3)

2.00e+5

Water Rate SC (m3/day)
2009 2010 2011 2012 2013 2014 2015 2016

200

1.00e+5

100

0.00e+0

0 2009 2010 2011 2012 2013 2014 2015 2016

Time (Date)
No ICD ICD - 225 m from heel, 54/46 split ICD - 225 m from heel, 67/33 split No ICD - 5" tubing

Time (Date)
No ICD ICD - 225 m from heel, 54/46 split ICD - 225 m from heel, 67/33 split No ICD - 5" tubing

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