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High-Rate Fracturing –
Open Hole (Bridging Agent Diversion)
High-Rate Fracturing –
Open Hole (Bridging Agent Diversion)
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Pinpoint StimulationPinpoint Stimulation
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Horizontal Well StimulationHorizontal Well Stimulation
Loyd East
Product Manager
Pinpoint Stimulation
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AgendaAgenda
Horizontal Well Fracturing Processes
• Processes for Open Hole Horizontals
• Processes for Uncemented Liners
• Processes for Cemented Liners
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Openhole or Slotted Liner CompletionsOpenhole or Slotted Liner Completions
SurgiFrac®
• Acid Fracs
• Proppant Fracs
• ‘Skin’ Fracs
• Dynamic
Diversion
• HWO or CT
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SurgiFrac®SurgiFrac®
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SurgiFrac® ServiceSurgiFrac® Service
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Hanifa HJAF CompletionHanifa HJAF Completion
0
1000
2000
3000
4000
5000
6000
0 100 200 300 400 500 600 700 800 900 1000
Days of Production
0
2000
4000
6000
8000
10000
12000
14000
16000
18000Water BWPD
Oil Rate BOPD
WHP psi
Gas MSCPD
Oil Rate, bopd
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Results SummaryResults Summary
• SurgiFrac increases the well productivity in more than 600%.
Oil production rate increased from 500 BOPD to 3,000 BOPD
using the same choke size for comparison purposes.• Permanent Gauge Information showed that the Productivity
Index “PI” from the well increased from 1.15 to 10.4 as a result
of the SurgiFrac process.
• SurgiFrac process permits the outstanding selective
stimulation of the horizontal well in 10 points without showing
stress interference.
• The well produces 5,400 BOPD with 80/64” choke size
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Offshore SurgiFracOffshore SurgiFrac
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SurgiFrac Brazil – New Deepwater WellSurgiFrac Brazil – New Deepwater Well
Recently completed the first treatment on a deepwater well for Petrobras in the Campos Basin, offshoreBrazil.
Petrobras comments:“ A global first - a stimulation job using the SurgiFrac
technique has just been completed from a floating
unit. This technique allowed for multiple fractures ina subsea, uncemented horizontal wellbore. Theapplication of this technology is expected toincrease the Recovery Factor of oil from thecarbonates in the Campos Basin …. It can now beconsidered that this technology is now available for application in whichever working environment –land, fixed platform and subsea.”General Engineering Manager
SPE 90056
®
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Delta Stim® Completion ServiceDelta Stim® Completion Service
• Delta Stim® sleeves
• Swellpacker™ Isolation Systems
• Acid Soluble Cement
• VersaFlex® Liner Hanger System
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Delta Stim® Completion ServiceDelta Stim® Completion Service
Pneumatic Ball Dropper
®M h i l Shift D lt Sti ® Sl
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Mechanical Shift Delta Stim® SleeveMechanical Shift Delta Stim® Sleeve
MS D lt Sti ® Sl Cl d OMS Delta Stim® Sleeve Close and Open
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MS Delta Stim® Sleeve Close and OpenMS Delta Stim® Sleeve Close and Open
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Swellpacker TM
Isolation System
Swellpacker TM
Isolation System
SwellpackerTM Isolation System
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SwellpackerTM Isolation System
Rubberbonded to pipe End rings
Standardoilfield tubular
• Forms part of completion string
• Does not require service tools• Swells to fill washouts
E ti t d/C l t d ∆P
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Estimated/Correlated ∆P
0
50
100
150
200
250
300
350
400
450
500
550
600
650
700
750
8.4 8.6 8.8 9 9.2 9.4 9.6 9.8 10 10.2 10.4 10.6 10.8
Hole ID [in]
D i f f e r e n t i a l p r e s s u r e [ b a r ]
0
725
1450
2175
2900
3625
4350
5075
5800
6525
7250
7975
8700
9425
10150
10875
D i f f e r e n t i a l p
r e s s u r e [ p s i ]
4.5inx8.15inx9m Sw ellpacker
5.5inx8.15inx9m Sw ellpacker
6.625inx8.15inx9m Sw ellpacker 7inx8.15inx9m Sw ellpacker
4.5″
5.5″
6.625″
7″
8.15″
The Swellpacker™ Lite Tool
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The Swellpacker Lite Tool
Swelling Element• 20 mm or greater thickness
Element Length• 1 meter (3.3 ft)• Full Internal & external seal
End Rings• aids deployment• elastomer support
SwellpackerTM Lite tool
• Slip on design
• 1,000 psi rated• Standard API casing sizes
• Custom sizes available
• Installed at wellsite or pipeyard
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VersaFlex® Liner Hanger SystemVersaFlex® Liner Hanger System
• No moving parts
• Eliminates pre-set risk• Reduction in leak
paths• Superior annular seal
• Simplified design
• Simplified procedures
Advantages of Expandable Liner HangersAdvantages of Expandable Liner Hangers
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Advantages of Expandable Liner HangersAdvantages of Expandable Liner Hangers
•Simplicity•Single redundant sealing area
◊Robust gas tight seal•No slips – no setting issues
◊No tortuous fluid flow paths◊No pre-set risk◊No place for well debris◊No tool release issues
◊Sets in any casing hardness◊Will not damage parent casing
•Improved cementing jobs◊Rotation and reciprocation
◊No liner top squeeze◊No liner shoe squeeze
Conventional
Liner Hanger
VersaFlex®
Liner Hanger
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InterventionlessDelta Stim ® Completion
System
InterventionlessDelta Stim ® Completion
System
Tracer Log after using Delta Stim® CompletionTracer Log after using Delta Stim® Completion
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SystemSystem
4-1/2” Delta Stim Completion utilizing Delta Stim Lites & Swellpacker Lites
• Horizontal Well
• Frac through 2.56” Baffle @
5733 ft
• Upper Swellpacker @ 5561 ft
• Lower Swellpacker @ 5875 ft
• 253,053 lbs of 40/70 premiumwhite sand
• Avg pump rate 92 bpm
• Avg pressure 6,650 psi
• Tracer – Sc-46 Zero Wash
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Cased/Cemented CompletionsCased/Cemented Completions
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Cased/Cemented CompletionsCased/Cemented Completions
Conductivity with Flow ConvergenceConductivity with Flow Convergence
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Conductivity with Flow ConvergenceConductivity with Flow Convergence
50 ft Perfs 0.5 ft Perfs
100 ft Frac – Fcd = 10
Two Cases:
-No Damage
-6 ft NW (Fcd = 1)
100 ft Frac – Fcd = 10
Three Cases:
-No Damage
-6 ft NW (Fcd = 1)
-6 ft NW (Fcd = 500)
Conductivity with Flow ConvergenceConductivity with Flow Convergence
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Conductivity with Flow ConvergenceConductivity with Flow Convergence
Cumulative Production
-600000
-500000
-400000
-300000
-200000
-100000
0
0 50 100 150 200 250 300 350 400
Time, Days
C
u m O
i l , B B l s
0.5 ft Perfs 50 ft Perfs 0.5 ft Perfs Packed 0.5 ft Perfs Damaged 50 ft Perfs Damaged
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CobraMax H
CobraMax V
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CobraMax
Wellhead
CobraMax BHACobraMax BHA
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CobraMax BHA• Coiled Tubing Connector
• Sheer Disconnect
• Centralizer
• Jet Body
• 3/16” Jets
• Ball Cage
• Ceramic Ball
• Lower Ball Sub• Mule Shoe Collar
Fracturing RatesFracturing Rates
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gg
Maximum Annulus Frac Rates for 1-3/4” Coil
3-1/2” Casing 11 bpm
4-1/2” Casing 25 bpm
5-1/2” Casing 36 bpm
7” Casing 55 bpm
Note – Requires a Dual Flow Cross at injection point on surface –
20 ft/sec Max Velocity from Inlets to prevent erosion of coil
Case History #1 South TexasCase History #1 South Texas
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yy
• Perdido Sand
• 10,680’- 11,917’ (MD)
• 10,550’- 10,630’ (TVD)• 6 Distinct Frac Targets
• 35# Sirroco Frac System – 30 bpm
• 1,080,500 lbs 20/40 Ceramic Plus Proppant
• 504,500 lbs 20/40 RC Ceramic Plus Proppant
• 3-1/2” Liner – Unperforated• 1-3/4” Coiled Tubing
Case History #1 ResultsCase History #1 Results
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yy
Hydra-Jet PerforatingHydra-Jet Perforating
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y gy g
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Schematic of Jet Stream in a Hydra-jettedPerforation TunnelSchematic of Jet Stream in a Hydra-jettedPerforation Tunnel
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Perforation TunnelPerforation Tunnel
Jet Stream Divergence and Full Returns
10 “
Schematic of Jet Stream in a Hydra-jettedPerforation Tunnel with Induced FractureSchematic of Jet Stream in a Hydra-jettedPerforation Tunnel with Induced Fracture
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Perforation Tunnel with Induced FracturePerforation Tunnel with Induced Fracture
6 ft
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SummarySummary
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• Openhole Horizontals – SurgiFrac• Sliding Sleeve Completion – DeltaStim Sleeves
and Swell Packers
• Cased/Cemented Horizontals – CobraMax H
• Moderate to High Perm Reservoirs require
Highest Near-Wellbore Conductivity possible• Low Risk, Aggressive Proppant Treatments
made efficient with Coiled Tubing methods
• Hydra-jet Perforating can stimulate passed
damage while perforating in high perm rock
Fracture Placement OptionsFracture Placement Options
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• Hydra-Jet Perforating (HP)
• Dynamic Diversion – Hydra-jet Assisted
Fracturing (HJAF)• Swell Packer Diversion
• Proppant Plug Diversion (HP) + Annular Fracturing
• Ball Activated Sliding Sleeves• Mechanical Shifted Sleeves
Ball Drop Delta Stim® SleeveBall Drop Delta Stim® Sleeve
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Delta Stim® Lite SleeveDelta Stim® Lite Sleeve
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FlexibilityFlexibility
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ForceForce
Time (days)
0
10
20
30
40
10 20 30 40 50
A new approach
to materials
– Rubber swells inhydrocarbons
– Activates in oil but
not pure water
– Creates effective
seal in open hole – Swell time adaptable
to suit environment
Estimated/Correlated ∆P
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• Manufactured to any pipe
diameter
• Slimmer pipe means thicker rubber
• More rubber means greater
swelling, for higher differential pressure
• Longer packer lengthincreases
differential pressure
capability• Swells to seal irregular
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