using near-wellbore rock deformation to enhance ... · • mechanical deformation of the wellbore...
TRANSCRIPT
IES - Global
Using near-wellbore rock deformation
to enhance productivity/injectivity
DEVEX 2011
The Production and Development Conference and Exhibition
By
Juan Tovar - Innovative Engineering Systems Global
Dave Noblett – Darcy Technologies Ltd.
Aberdeen, [11-12] May 2011
IES - Global
AGENDA
• Factors affecting productivity at the near wellbore
• Near wellbore mechanical performance during Drilling &
Production
• Enhancing productivity/injectivity using deformation
• Permeability test change verification
• The Concept of Critical Matrix Management
• Equipment development process, specifications and features
• Summary
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FACTORS AFFECTING NEAR WELLBORE PERFORMANCE
Courtesy of Petroleos de Venezuela S.A.
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FACTORS AFFECTING NEAR WELLBORE PERFORMANCE
Solids invasion
• Bridging – Mud cake
• Shallow invasion
• Single pore blocking
• Combined invasion
• Deep invasion – No plugging
Pore throat
partly blocked
Pore throat clear Pore throat
fully blocked
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NEAR WELLBORE MECHANICAL PERFORMANCE
• During drilling the sand face will suffer from deformation that might lead to changes in ϕ-K
• During production the wellbore will continue to deform depending on depletion and drawdown applied
• Changes ϕ-K in can lead to an “additional” positive/negative skin
• Physics of near wellbore deformation developed from mining and geotechnical engineering
• Limited application to wellbore performance, concept used in wellbore stability problems
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NEAR WELLBORE DEFORMATION – Prediction
• Caused by the drilling process
• Almost unavoidable
• A permanently deformed extension around the wellbore
• Mud weight, stress field and pore pressure dependant
• Results match measured calliper
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8.00
12.00
16.00
20.00
24.00
28.00
010
2030
40
50
60
70
80
90
100
110
120
130
140150
160170
180190
200210
220
230
240
250
260
270
280
290
300
310
320330
340350
Hole deformation at 8027.5 MD (feet)
Bit Size Rp
8.00
12.00
16.00
20.00
24.00
010
2030
40
50
60
70
80
90
100
110
120
130
140150
160170
180190
200210
220
230
240
250
260
270
280
290
300
310
320330
340350
Hole deformation at 9000 MD (feet)
Bit Size Rp
NEAR WELLBORE DEFORMATION MODELING
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After Palmer I. 2000
NEAR WELLBORE MECHANICAL DEFORMATION – Dilatant bands
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NEAR WELLBORE DEFORMATION – Constitutive models
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Change of Porosity and Permeability - Non Consolidated Formation
Range (MD) : 5850.00' - 6200.00'
Scale : 1:1000
5850
5900
5950
6000
6050
6100
6150
Original K10 10400mD
Original Porosity0 0.5Frac
K_change DD= 100 psi0 160%
K_change DD=5000 160%
K_change DD= 800 psi0 160%
K_change DD = 1100 psi0 160%
Por_change (DD = 100 psi)0 20%
Por_change (DD = 500 psi)0 20%
Por_change (DD = 800 psi)0 20%
Por_change (DD = 1100 psi)0 20%
Inflow (DD = 100 psi)0 500bpd
Inflow (DD = 500 psi)0 500bpd
Inflow (DD = 800 psi)0 500bpd
Inflow (DD = 1100 psi)0 500bpd
NEAR WELLBORE DEFORMATION – Change in K, ϕϕϕϕ
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NEAR WELLBORE DEFORMATION – Critical Matrix Management
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NEAR WELLBORE DEFORMATION – Testing (FracTech 2011)
SupportedCastlegate sand
2011
UnsupportedCastlegate sand
2011
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NEAR WELLBORE DEFORMATION – Changes in K
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CONCEPT OF CRITICAL MATRIX MANAGEMENT
Ability to put theory into practice by applying a radial force to the near wellbore.
Re-stress the formation and control deformation during production
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SAND FACE COMPLETION – FUNCTIONS & SOLUTIONS
Functions Solutions
Positive compliance Allows the management of sand mobilisation
and formation deformation
System integrity Collapse resistance and wellbore access
Deployment and activation Simple pressure activation from surface – no control lines, complex pumping operations or expansion runs
Inflow control Integration of ICD and compliance in one system
Zonal Isolation Through the use of swellables or standard
packers
Wellbore and formation isolation
Formation Isolation devices are easily incorporated into the one trip system
Higher productivity Positive compliance allows for greater drawdown to be placed on the formation
Solids control Premium retention and minimized plugging
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Drainage / Support LayerDrainage / Support Layer
Sand Filter MediaSand Filter Media
Base PipeBase Pipe
Tri-Axial Activation ChamberTri-Axial Activation Chamber
Production Flow ChannelsProduction Flow Channels
Protective shroud
Protective shroud
SAND FACE COMPLETION SYSTEM
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ACTIVATION MECHANISM - Testing
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CONCLUSIONS
• The near wellbore area is critical to the production/injection
optimization process, a large number of factors can affect the final
well performance (fluids & solids invasion, chemical interaction..)
• Mechanical deformation of the wellbore always occurred but it is
poorly understood and its impact on production/injection not
quantified…so far.
• This work undertook the application of rock deformation principles
to the near wellbore area in order to identify potential benefits for oil and gas production / injection
• By varying the stresses around the wellbore, porosity and
permeability changes can be managed to optimise
production/injection
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CONCLUSIONS
• The concept of Critical Matrix Management has been presented to
define the boundaries under which deformation can result in
production enhancement.
• The implementation of this process is carried out through a unique
innovation which allows wellbore functions (wellbore support, inflow & sand control, deformation) to be carried out in an integral manner
• Extensive testing and modelling work proves that it can be done
effectively with minimum operational risk.
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SYSTEM SPECIFICATIONS
Feature 8 ½” System 6” System
Openhole Size (in./mm) 8 ½ / 215.9 6 / 152.4
Base Pipe Material Low Carbon SteelL80 13Cr
Low Carbon SteelL80 13Cr
Base Pipe Size (in./mm) 6 5/8 / 168.3 4 / 101.6
Connection Type 6 5/8” Vam Top 4” Vam Top
Base Pipe Weight 24 13.2
Overall Weight 45 27
Running OD (in./mm) 7.75 / 196.9 5.1 / 130.2
Running ID (in./mm) 5.26 / 133.6 3.3 / 84.5
Activated OD Range (in./mm) 7.75-10 / 196.9-245.0
5.1-7.2 / 130.2-182.9
Petroweave Size (µm) 120,150, 230, 270 120,150, 230, 270