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Enhancing Hydraulic Fracturing and Well Performance via Effective Diversion
FRAGACHAN, FRANCISCO E.
MEDINA ZARATE, CARLOS
Weatherford1
Which of these wells is P&P completed?
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Outline
• Product Overview• Technology Benefit• Applications• Case Studies• Modeling and Verifications• Experimental Collaboration with TOTAL• Conclusions
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Product OverviewGreen technology allowing more efficient fracturing completions and the ability to re‐fracture/re‐stimulate existing wells and improve upon overall production via in‐stage diversion.
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Borrowing Green Technology
• Made From Renewable Materials• Certified Compostable• Used in Medical Industry for Implantable Degradable Devises
• Used for Degradable Packaging Materials• Byproduct is Naturally Occurring in Human Body• Allows to Restore Production or Increase Well Efficiency
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An Alternative to Current Diversion Methods : Mechanical Diverter System
• Mechanical Bridging Agent• Degradable to Liquid Form• Temperature Range
• (83°F – 300+°F)
• Aqueous Fluid System Compatibility• Two Particle System: 100 & 7 US Mesh (1.23‐1.25 SG)
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Product OverviewLong‐Term Degradable Diverters
• When operations are suspended, ball sealers will fall away from the perforations, rock salt and flake diverters rapidly dissolve.
• This creates a need for a material that will remain in the perforations for multiple stages and dissolve over time.
• Degradable mechanical diverters are an environmentally friendly, mechanical diverter that addresses these criteria.
Cylindrical Shape:
Plugging Efficiency
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Technology Benefits• Effectively Blocks Existing Perforations
• 300 – 1,200 psi increases typical
• Stable Under Large Pressure Increases• 6,000 psi pressure increase achieved
• Diverts Fluid to New Perforations• Divert Fluid to Under‐stimulated Clusters
• Remains in Perforations/Near Wellbore
• Superior to traditional diverting agents
• System Dissolves Over Time• No Plug Mill‐outs / No Squeezed Perforations
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Marcellus Shale Treatment Plot
Time (min)
Pressure 1 (psi)
515.0 517.0 519.0 521.0 523.0 525.03000.00
4500.00
6000.00
7500.00
9000.00
10500.00
9980 ps iBio Bloc k @ perfs ,
6125 ps i
Marcellus Treatment Plot
Time (min)
Pressure 1 (psi) Slurry Rate (bpm)
178.0 180.8 183.6 186.4 189.2 192.04000
5300
6600
7900
9200
10500
0.0
24.00
48.00
72.00
96.00
120.0
8,862 ps i
5 ,970 ps i
8 ,460 ps i
9 .594 ps i
5 ,361 ps i
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Applications
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– Replace all bridge plugs or reduce total needed
– Reduce or eliminate mill‐out time and equipment
– Provide zonal isolation
Replace Bridge Plugs
– Size limitations/ restrictive ID’s
– Weak casing limiting entry
– Open Holes/Stuck Casing
– LCM
Casing & ID Restrictions
– Perf‐squeeze Alternative
– Recompletes & Re‐Fracs
– Understimulated zones
– Sliding sleeve port seal
Multiple Open Clusters
The Importance of Zonal Coverage Distribution
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In‐Treatment Diversion Case Study
Five Horizontal Eagle Ford Shale Wells
Depth: 9,000’ TVD
BHST: 250°F 54 perforations per interval
One & two diverter pills based on well 11
Case Study Criteria
• Effectively Diverter a Portion of Perforations During Treatment
• After Each Stage a Plug Will be Set for Isolation• Determine if In‐Treatment Diversion Will Increase Zonal Coverage & Production
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In Treatment Diversion
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Key Statistic
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In‐Treatment Diversion Case Study #2
Tow Horizontal Eagle Ford Shale WellsDepth: 8,370’ TVDBHST: 244°F One diverter pill per stage
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Key Statistic Untreated Offset Wells
#1
Untreated Offset Well
#2DiversionWell #1
DiversionWell #2
TVD (ft) 7930 8282 8387 8369
Lateral Length (ft) 10223 7101 7530 7972
Proppant per lateral foot 1614 Data is N/A 1370 1340
30 Day Oil Production(BBL/Day) 222 212 390 413
30 Day Oil Production (BBL/Day/1000' of Lateral) 21.7 29.9 51.8 51.8
30 Day Gas Production (MCF/Day) 113 149 209 208
30 Day Gas Production (MCF/Day/1000' of Lateral) 11.1 21.0 27.8 26.1
Total Production (BOE/Day/1000' of Lateral) 23.6 33.4 56.4 56.2
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Key Statistic Untreated Offset Wells
#1
Untreated Offset Well
#2DiversionWell #1
DiversionWell #2
TVD 7930 8282 8387 8369
Lateral Length 10223 7101 7530 7972
Proppant per lateral foot 1614 Data is N/A 1370 1340
30 Day Oil Production(BBL/Day) 222 212 390 413
30 Day Oil Production (BBL/Day/1000' of Lateral) 21.7 29.9 51.8 51.8
30 Day Gas Production(MCF/Day) 113 149 209 208
30 Day Gas Production (MCF/Day/1000' of Lateral) 11.1 21.0 27.8 26.1
Total Production (BOE/Day/1000' of Lateral) 23.6 33.4 56.4 56.217
Results
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Percent Increase
DiversionWells showed 30 day productions improvement of
83%
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NR Tracer Monitoring DP1H
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Results Well 1
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Results Well 2
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ReFrac Case StudyPermian Basin Vertical Well Study
Depth: 8,900’ – 9,800’ TVD
BHST: 135°F – 140°F 480 Perforations
Combine multiple stages into one utilizing diverter23
Permian Basin Vertical ReFrac Well
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Permian Vertical Multiple Stage Completion Case Study• Achieved Zonal Isolation without Bridge Plugs• Long‐term Perf Sealing and Diversion Compared to Traditional Diverters
• No Plug Millouts Post‐Treatment• Waiting for Production Results• Tracer Logs Showed True Zonal Sand Distribution
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ReFrac Case StudyPermian Basin Vertical Well Study
Depth: 8,900’ – 9,800’ TVD
BHST: 135°F – 140°F 480 Perforations
Combine multiple stages into one utilizing diverter31
Case Study Criteria
• Effectively Replace Bridge Plug Use By Sealing Existing Perforations
• Achieve 1,000 psi Increase or 7,000 psi TP Per Run• Run diverter slugs until achieved
• No Well Intervention Needed• Eliminate Plug Mill‐out • Eliminate Coiled Tubing• Increase Customer Efficiency
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Well 1• (March 2013), P&P• 3727’ LL, 13 stages (100’spacing) w/300x300•
Well 2• (Oct. 2013), TBlockSure®• 5353’ LL, 18 stages (50’spacing) w/300x300
Wel l 4• Completed (Oct. 2013), P&P• 6353’ LL, 32 stages (50’spacing) w/200x200
Wel l 3• (Oct. 2013), P&P• 4753’ LL, 24 stages (50’spacing) w/200x200
Pad Layout
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Job Execution
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Pressure Increase, Some Perf Diversion
Diverter pill with multiple perforation diversions and breakage observed.
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Marcellus Shale Treatment Plot
Time (min)
Pressure 1 (psi)
30.00 35.00 40.00 45.00 50.00 55.005000.00
5400.00
5800.00
6200.00
6600.00
7000.00
Diverter @ perfs, 5387 psi
5809 psi
422 psi increase
Pressure Increase, PerfDiversion
Diverter pill with multiple perforation diversions and breakage observed.
Marcellus Shale Treatment Plot
Time (min)
Pressure 1 (psi)
135.0 137.0 139.0 141.0 143.0 145.05000.00
5300.00
5600.00
5900.00
6200.00
6500.00
Diverter @ perfs, 5227 psi
5859 psi
669 psi increase
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Pressure Increase, Perf Diversion
Diverter pill with multiple perforation diversions and breakage observed.
Marcellus
Time (min)
Pressure 1 (psi) Slurry Rate (bpm)
264.0 264.5 265.0 265.5 266.0 266.56000
6500
7000
7500
8000
8500
0.0
16.00
32.00
48.00
64.00
80.00
6,722 psi
7,955 psi7,217 psi
1,233 psi increase
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Pressure Increase, Perf Diversion
Diverter pill with multiple perforation diversions and breakage observed.
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Marcellus Treatment Plot
Time (min)
Pressure 1 (psi) Slurry Rate (bpm)
150.0 151.1 152.2 153.3 154.4 155.56000
6500
7000
7500
8000
8500
0.0
20.00
40.00
60.00
80.00
100.0
6,801 psi
7,902 psi
8,083 psi 7,990 psi8,008 psi
1,282 psi increase
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Pressure Increase, Perf Diversion
3,624 psi pressure increase.
Marcellus Treatment Plot
Time (min)
Pressure 1 (psi) Slurry Rate (bpm)
178.0 180.8 183.6 186.4 189.2 192.04000
5300
6600
7900
9200
10500
0.0
24.00
48.00
72.00
96.00
120.0
8,862 psi
5,970 psi
8,460 psi
9.594 psi
5,361 psi
3,624 psi increase
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Intentional Screen‐Out Using DiverterFinal batch of diverter used to seal remaining perforations. 3,855 psi pressure increase.
Marcellus Shale Treatment Plot
Time (min)
Pressure 1 (psi)
515.0 517.0 519.0 521.0 523.0 525.03000.00
4500.00
6000.00
7500.00
9000.00
10500.00
9980 psiBio Block @ perfs,
6125 psi
3,855 psi increase
4040
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Well 1 & 2 Total Wellbore Cloud
4141
Near Well TFI (view from above)
Near‐Wellbore TFIs for Both Wells
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Modelling and VerificationCollaboration with TOTAL
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Collaborative Research : Total
• Slots were placed in pressure vessel and diverting slurry pumped under pressure to determine if diversion would occur
• Monitored by differential pressure across slot
• Monitored mass of effluent flowing thru with time
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Collaborative Research : Total
• Metallic Slots with various size opening were evaluated for diversion
• 1 mm to 5 mm
• Uniform in shape throughout entire length
• No adherence points
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Collaborative Research : Total
• Carbonate Slots with various size opening were evaluated for diversion
• 1 mm to 6 mm• Irregular shaped opening
• Opening size tapered from inlet to outlet
• Simulates perforations / natural fractures
• Naturally rough surface
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Collaborative Research : Total
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What Have We Learned?1 mm Slot Opening Metallic
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What Have We Learned?5 mm Slot Opening Carbonate
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Physics & Modeling 1 mm
2 mm
3 mm
4 mm
5 mm
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Modeling – Other ParametersBase
Simulation
Small Particles
Particle Shape Geometry
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Plug existing Perforations
Field Data
Analytical
Numerical
Experimental
Diverting Agen
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Particle Ratio
Particle Ratio
15:85 50:5030:70 40:60
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Next Experiments
Concentration (ppg)
Particle Ratio
Pressure Build‐up
0.5 1.0 1.5 3.015:85
30:70
40:60
50:50
M = Metallic Slot Test (1 mm, 3 mm, 4 mm and 5 mm)C4 = Carbonate Test (4 mm – 2 mm)
5.0
M M
C4
C4
C4
C4
C6 = Carbonate Test (6 mm – 2 mm)
C6C6
Rate (mL/min)
10 100Slot Size (mm)
4 10Particle Shape
Spherical Cylindrical
Cy = Cylindrical Particles
CyCy
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Conclusions
• Degradable Diverter Advantages• Extensive BHT Range for Products• More efficient perforation sealing & diversion• Remains in perforations long term & degrades
• Potential Candidates• Re‐Completes / Re‐Fracture Treatments• Temporary Perf Squeeze Alternative• In‐Treatment Diverter
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Thank You For Your AttentionQuestions?
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