Transcript AccessFrac Service

Method to Help Improve Long-Term Production
Following Shale Fracture Treatments
Dave Allison
October 31, 2011
AccessFracSM Service
Poor Proppant Distribution
Not Contacting Enough of
the Reservoir
Hindered Hydrocarbon
Production
Method to Help Improve Long-Term Production
Following Shale Fracture Treatments
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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AccessFrac Service
Dave Allison
Tenet Manager – MSRV
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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AccessFrac Service
Poor Proppant Distribution
Not Contacting Enough of
the Reservoir
Hindered Hydrocarbon
Production
Method to Help Improve Long-Term Production
Following Shale Fracture Treatments
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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AccessFrac Service
Improved Proppant Distribution
Computer Modeling Studies
Analysis of Microseismic Mapping
Analysis of Production Logs
Lower than Expected Initial Production
Faster than Expected Production Declines
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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Improved Proppant Distribution
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Improved Proppant Distribution
Near Wellbore
Temporary Blockage
Self Removing
Environmentally Friendly
Highly Compatible
BioVert® NWB material
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AccessFrac Service
Traditionally use drillable bridge plugs to isolate clusters
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Physical barrier
Means to deliver perforating guns
Highly reliable
Drillable
Improvement Opportunities / Risk Mitigation
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Reduce time – installation
Reduce time – removal
Reduce risk – premature set or perforating
Reduce cost – displacement fluids
What other mechanism can we use to isolate clusters?
Biovert ® NWB Self-Degrading Diverting Agent
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Traditional - Plug and Perforate
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Pump perforating gun and frac plug on depth
Set the frac plug
Correlate perforating gun and perforate
Pull out of the hole
Time requirements 3-5 hours
Repeat the process 15 – 30 times
Equipment standby time between 2 and 7 days
At conclusion the plugs have to be drilled out using a rig
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AccessFrac Service
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Group 2 or 3 perforation clusters
Pump perforating guns and frac plug on depth
Pump frac treatments followed by diverters
Repeat as needed to cover lateral
Savings – Time 6-10 hours (perf & plug ops) per group
Savings – Time 1-4 days (equipment stand-by ) per well
Savings – Safety: reduce perforating exposure
Reduce - Risk of bridge plug setting prematurely
Savings – Cost of 66% of bridge plugs
Savings – Time reduce drill out ops by 66%
Savings
– Reduced
displacement fluid by 66%
To clean well
out:
Savings
– Diverter
– Time
self degrades
(faster) for fluid flow back
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© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
Plugs drilled out using rig
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Achieve much better
access to complex
fracture networks
New Completion Denton County – Horizontal Well
Replace Pump Down Plug
Case History 21 - 2010
Treatment Chart:
1st Biovert NWB on
perforations +60 psi
increase
2nd
3rd
2nd Diverter gives 115
psi increase
1st
3rd Diverter gives 1542
psi increase
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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New Completion Denton County – Horizontal Well
Replace Pump Down Plug
Case History 22 - 2010
Treatment Chart:
Biovert NWB agent on
perforations +916 psi
increase
Biovert NWB
Results: Saved considerable time and expense. Production equals offsets.
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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AccessFrac Service
Poor Proppant Distribution
Not Contacting Enough of
the Reservoir
Hindered Hydrocarbon
Production
Method to Help Improve Long-Term Production
Following Shale Fracture Treatments
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
13
AccessFrac Service
Enhanced Reservoir Contact
Analysis of Microseismic Mapping
Analysis of Production Logs
Lower than Expected Initial Production
Faster than Expected Production Declines
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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Deep Reservoir Diversion Candidate
Non Stimulated Area
Stage 3
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Non Stimulated Area
Stage 4
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Enhance Reservoir Contact
Deep Reservoir
Temporary Blockage
Self Removing
Environmentally Friendly
Highly Compatible
BioVert CF material
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
16
AccessFrac Service
Poor Proppant Distribution
Not Contacting Enough of
the Reservoir
Hindered Hydrocarbon
Production
Method to Help Improve Long-Term Production
Following Shale Fracture Treatments
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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Customizable Conductivity
26% Porosity
48% Porosity
65+% Porosity
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
85+% Porosity
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Customizable Conductivity
Surface Modification Agent
Enhanced Conductivity
Water Based System
30% more
conductivity
SandWedge® ABC enhancer
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Highly Compatible
SandWedge Enhancer
Family
100,000+ applications
6 Month Cumulative Production
3000000
SandWedge
Enhancer
2500000
SandWedge
W
Chudleigh 3H-NW
No. 28H
TEEL
BLACK
No. 3 1H
2000000
ELY
No.6H
4
No. 5
HUBBARD
5H
Gas (Mcf)
6 3H
RNo.
SMITH
No. 7
HUBBARD
6H
No. 8
GESFORD
7H-NW
1500000
BLACK
No. 9 2H
10
B No.
SEVERCOOL
2H-NW
R No.
SMITH
11 1H
ELY
No.4H
12
1000000
J No.
GRIMSLEY
2H-SE
13
No. 14
HEITSMAN
4H-NW
RATZEL
No. 15 2H
ELY
No.1H
16
500000
0
1
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AccessFrac Service
Complex fracture
network with
proppant using
AccessFrac
service
Typical shale
fracture without
diversion
Method to Help Improve Long-Term Production
Following Shale Fracture Treatments
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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AccessFrac Service
Poor Proppant
BioVert Distribution
NWB
Not contacting enough of
BioVert
CF
the
reservoir
Hindered Hydrocarbon
SandWedge
ABC
Production
Method to Help Improve Long-Term Production
Following Shale Fracture Treatments
© 2011 HALLIBURTON. ALL RIGHTS RESERVED.
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AccessFrac Service
Thank you
Halliburton Energy Services
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