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Using a new Intelligent Well Technology Completions Strategy to Increase Thermal EOR RecoveriesSAGD Field Trial
Authors:
Mark Bedry &
Joel Shaw
Halliburton WellDynamics
2 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Agenda
• SAGD basics and issues• Ideal Solution • Understanding the reservoir• Advantages of Actively controlling a SAGD system• Trial description and results
3 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
SAGD Theory
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Heel injectionToe injection
SAGD Current Solution
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• Barbell Shaped Steam Cavern
Some Traditional SAGD Problems
• Poor Injectivity
• Steam Breakthrough
• Lack of Conformance
6 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
The Outcome…• Uneven steam chamber development• Reduced oil rates• Higher steam oil ratio (SOR)• Lower recovery
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What’s the Solution?
X X X X
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Actively Control the System• Control Injectivity
• Transient Temperature & Pressures at Shut-in (no Work over)
• See Steam cut before it can cause damage
• React to changes that have been made
9 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Understanding the Chamber
Pressure Monitoring• Gas Column• Fibre Optic Pressure
Gauge
Temperature Monitoring• Distributed Temperature Sensing (DTS)
Surface Deformation• Seismic• Tilt Meters• Insar
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Fibre Optic P/T Gauge
11 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
fiberlaser
detection
backscatteredlightlaser pulse
Depth to reflection determined by total
travel time
DTS Box
TemperatureFunction of Raman Stokes and Anti-Stokes Backscatter
Distributed Temperature Sensing
12 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
High Temperature Seals
Injection/Production Ports
Hydraulic Control ConnectionsOpen & Close with Feed Through
Piston Chamber
Inner Mandrel (Sleeve)
Thermal ICV
13 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Hydraulic Control
Dedicated Lines
Common Return Line
5
1 2 34
14 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Surface Hydraulic Control Unit
15 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Wellbore segmentation
• Interference fit for steam diversion• Centralization for protection• Splice-less Feedthrough for control lines • 315degC rated
Centralizer
Control lines
Diverter element
16 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Trial Completion
• Pre-built high temperature fibre DTS system (single and multi-mode) to valve D
• Fibre based pressure and temperature gauges at valves B, C, D• Fluted Centralizers • Torque & Drag Modeling used to ensure success
17 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Baseline data comparison
110130150170190210230
500 600 700 800 900 1000 1100 1200 1300
Depth (m MD KB)
Te
mp
(d
eg
C)
15-16Core
OB1
OB2
11-16Core
WP1
WP2
WP4
WP3
15-16Core
OB1
OB2
11-16Core
WP1
WP2
WP4
WP3
ICV-A ICV-B ICV-C ICV-DICV-A ICV-B ICV-C ICV-DICV completionzones
Seismic thermal response
DTS temperature profile
Steaminjectivity
0.00.20.40.6
0.81.0
Zone A Zone B Zone C Zone D
II (
t/d
/kP
a)
E stim a te dE rro r
Injector
Producer
Heel
18 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
First Thermal ICV Installation
Installed in Shell - Orion Field Installed late 2009 went on steam early 2010 Installed in an Injector Installation included 4 sSteam valves, DTS,
Steam Diverters, and Fiber Gauges
ZONE A
ZONE B
ZONE C
ZONE D
19 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Upon Initial recompletion
Almost all of the steam injection went into Toe
There was evidence of the Steam Cavern being of a smaller diameter on the Heel
The Heel showed poor injectability with the Toe closed
ZONE A
ZONE B
ZONE C
ZONE D
``
20 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Injection Valve Schedule
– Injection into A, B, C, D for one week– Injection into A and B for 3 weeks– Close all zones for a day to watch the
temperature transients using the DTS– Repeat
Originally, most of the steam was going to the Toe of the completion. To combat this, the following injection schedule was used:
ZONE A
ZONE B
ZONE C
ZONE D
21 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Results Since Recompletion
– The ability of the ICV and Steam Diverter to control flow in a SAGD Environment has been proven
– Mechanical Integrity of key components have been proven– Increased Injectability in the heel section– Increased steam conformance– 35-40% improvement in SOR (Steam Oil Ratio)– 40-50% uplift in bitumen production– Results were published last year in SPE 137133
```
ZONE A
ZONE B
ZONE C
ZONE D
22 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Acknowledgements
• Shell Canada Ltd.• Halliburton WellDynamics• Operations & Engineering teams from both
companies
23 © 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Authors: Mark Bedry & Joel Shaw Halliburton WellDynamics
Thank you !
Questions?
