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Oriented Fracturing A Practical Technique for
Production Optimization
F. Fragachan
Schlumberger Oilfield Services
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Why Oriented Fracturing?
Address near-wellbore complexities Friction pressure losses:
Tortuosity, Misalignment, Pinch
Points, Multiple, Competing
Fractures
High frac gradients
Tectonically stressed areas
where placement is a problem
Premature screen-outs
Sand Control (FracPACK, Screenless)
Pin-Point Completions Tip#1
Tip#1
Frac
Fracalon
gPFP
alongPF
P
MinimizesMinimizesto
rtuosity
tortuo
sity,,
mislaign
ment
mislaign
ment andmu
ltiple
andmultipl
e
fracture
sfrac
tures
Tecton
icallyst
resseda
reas
Tectoni
callystr
essedar
eas
whereplac
ementis
aprobl
em
whereplac
ementis
aproble
m
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Oriented Fracturing - Hydraulic Fracturing Optimization
Treatment Optimization:
Increase the number of holes directlyopen to the fracture
Reduce near-wellbore complexities(tortuosity)
Fluids: shear, viscosity - Improvesability to fracture with less damagingfluids (water, hybrids, LG, VES)
Increase sand concentrations andvolumes
And/or larger proppant sizes
Minimize risk of premature
screen-out
Reduce fracture treating pressures
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Completion Optimization
GeoMechanical Model
The PFP orientation must be
determined
Perforating strategy and fracture
placement
Input for fracture stimulation
Added Value
Impact on Completion
Impact on Well Production andEconomics
b dca
Stress
De
pth
Zone
ofInterest
Stress
De
pth
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SPE 71652SPE 71652SPE 71652SPE 71652
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GeoMechanical Model
Reservoir Characterization
Multilayered/Multizone DescriptionRock Mechanics Stress ContrastPreferred Fracture Plane OrientationReservoir Mechanisms
Completion Modeling & Design
Development Strategy
Interpretation &
Integration
k, h, , Sg, Sw, pr,pc,c, E, , f
GeoMechanicalModel
Production Analysis
Drainage Area, Reserves
Decline Analysisq w, qg, Pwf, keffective , Xf, kfwf, FCDNon-Darcy Flow, Multiphase effects
Systems Analysis: Performance & LiftingCompletion Efficiency
InputData
OptimumCompletion
Strategy
Economic EvaluationOptimum Design
Maximum Productivity
Engineering FeasibilityPerformance PredictionAlternative Completions
What If Scenarios
Production Modeling
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Lower Treatment Pressures
Oriented Fracturing
Conventional Fracturing
Tip#2
Tip#2
Pressure
Pres
sure
Requirement
s
Requirement
s
Minim
izes
Minimiz
estortuosit
y
tortuosity an
dand
nearnear--we
llbore
wellbore
friction
friction
Lower
treatm
entpres
sures
Lowert
reatmen
tpressu
res
&HHPrequi
rements
&HHPrequi
rements
Reduce
dRed
ucedScreen
out
Screenout
Risks
Risks
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Pressure Requirements
Morrow Sand New Mexico
Placed 50% more proppant than waspreviously thought possible based on
experience in the area
Higher proppant concentrations
from 0.5 - 2.0 ppa to 3.5 - 4.0+ ppa
Wells treated 1000-1500 psi lower thanconventional fracs
TSO Design for better conductivity atwellbore
Conventional Fracs
Oriented Fracs
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Lower Near Wellbore Friction Pressures
Diatomite
GeoMechanical Model PFP
Rock Mechanics data
Minifracs for calibration
Comparison with direct offset wells Friction pressures reduced by as
much as 87% (50% on average)
Treatment pressures reduced by
as much as 31% (15% average)
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Placement and Design
Granite Wash
GeoMechanical Model - PFP Cleaner Fluid - VES
Real-time analysis and remotetransmission
Minimal near-wellbore
pressure losses
Increased sand concentration
6500 7500 8500
Stress - psi
11950
12000
12050
12100
12150
12200
12250
WellDepth-ft
-0.2 -0.1 0 0.1 0.2
ACL Width at Wellbore - in
0 250 500 750
Fracture Half-Length - ft
< 0.0 lb/ft2
0.0 - 0.3 lb/ft2
0.3 - 0.5 lb/ft2
0.5 - 0.8 lb/ft2
0.8 - 1.0 lb/ft2
1.0 - 1.3 lb/ft2
1.3 - 1.6 lb/ft2
1.6 - 1.8 lb/ft2
1.8 - 2.1 lb/ft2> 2.1 lb/ft2Zone of
Interest
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Completion OptimizationAntelope Shale & Monterrey Formation
Traditional Completion
1 job 75,000 lbs (60% job)
Nat frac sweet spot
Cleanup problems
History to date Cant pump design
Screen out on pad 0.25-0.5 ppa Sand slugs never worked
Success Ratio 1/20 !!!!
Oriented FracturingOriented FracturingOriented FracturingOriented Fracturing
GeoMechanical Model
PFP - Oriented Perforations
Stress profile and Minifracs
for Calibration
Nat.fracs - Modified fluids forpressure dependent leakoff
Job Size; 300,000 lbs - 4,000 bls
Concentration
3 ppa tailing with 4 ppa
Good proppant pack at wellbore
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Completion ResultsWell Type # - Completion Option Completion Proppant Pmax f
Details Volumes psi psi/ft
Well # 1 - Brown Shale / Diatomite 4 to 6 spf / 45oto 60
o/ 0.22" to 0.32" ~25,000 lbs; 20/40 Jordan 2499 - 3000 0.65 - 0.73
10+ Wells, Stages (3+), Point Source/LE XL 30# 35#
Oriented Perforating/Fracturing 4spf / 180o
/ 0.4" 120K lbs - 300K+lbs; 20/40 Jordan 1000 - 1500 0.55 - 0.602 well, 3 Stages Low Guar -25#
Well # 2 - Morrow Formation
10+ Wells, Traditional Completion - LE 4spf / 45 - 60o/ 0.32" 25K - 40K lbs; 20/40 CarboLITE 4800 0.68 - 0.7
Oriented Perforating/Fracturing 6spf / 180o/ 0.32"/Underbalanced 50K - 60K lbs; 20/40 CarboLITE 3800 0.62 - 0.65
2 Stages WF240 70Q FOAM
Well # 5 - Tight Oil Sand / California
10+ Wells, Blanket/Selective 4 to 6 spf / 60oto 90
o/ 0.32" to 0.5" 0 lbs; 20/40 Ottawa Screenout 0.7 to 1.2
3 wells - Oriented Perforating/Fracturing 4spf / 180o/ 0.4" 300,000+ lbs; 20/40 Ottawa ~ 5500 0.75 - 0.85
Well # 7 - Lobo Fm / South Texas
10+ Wells, Limited Entry Completion 4 to 6 spf / 45oto 90
o/ 0.22" to 0.32" 300,000+ lbs (20%); 20/40 Jordan 9900+/Screenout 0.75 - 0.95
1 Stage - Oriented Perforating/Fracturing 4spf / 180o/ 0.4" 282,000 lbs; 20/40 Econoprop 8163 0.645
YF835HT w/10# J353 96,000 lbs; 20/40 SHS High tortuosity eliminated
Well # 10 - Mckee Sand; Gas Reservoirs
Traditional Completion - Limited Entry 4 spf / 60o
/ 0.32" 15,000 - 20/40 sand 8000+ / ScreenoutOriented Perforating/Fracturing 4spf / 180
o/ 0.32"/Clustered Perfs 50,000+ - 20/40 Econop 4000 - 5000 0.66 - 0.75
YF340LPH 65Q FOAM
Tip#3
Tip#3Increased
IncreasedProppantProppant
Volumes
Volumes
HigherSandConcentrations
HigherSandConcentrations
LargerLargerProppant
ProppantSizesSizes
Connectivityto
Connectivitytowellbore
wellbore
Directrelationto
Directrelationtokk
ffwwffandand
productivity
productivityNo
Noproppantflowback
proppantflowback
observed
observed
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Production ResultsPropped Fracture
Well Type # - Completion Option f Xf k fw f Oriented Fracturing
psi/ft ft md-ft Production Results
Well # 2 - Morrow Formation
10+ Wells, Traditional Completion - LE 0.68 - 0.7 516 773 qgas~ 1.5mmcf/d @ 500 psi
2 Stages - Oriented Perforating/Fracturing 0.62 - 0.65 271 414 qgas~ 3.0+ mmcf/d @ 1200 psi
Well # 3 - Rockies/Tight Gas Sands
Traditional Completion - Limited Entry >1.0 400 730 From qgas~ 0.0 MMSCFD to qgas=1.0+ MMSCFD
Traditional Completion - Limited Entry >1.0 285 1579 From qgas~ 2.5 MMSCFD to qgas=4.5+ MMSCFD
Oriented Perforating/Fracturing 0.9 675 1126 From qgas~ 1.0 MMSCFD to qgas=3.5+ MMSCFDstabilized production
Well # 4 - North Sea
Oriented Perforating/Fracturing 0.87 200 800 From qoil=150 BOPD
To: qoil=3000+ BOPD, FTP = 3000+ psi, 3-5% WC
Well # 10 - Mckee Sand; Gas Reservoirs
Traditional Completion - Limited Entry qgas= 500 MCFD (FTP 700#)Oriented Perforating/Fracturing 0.66 - 0.75 qgas = 2.0 MMCFD (FTP 1300#)
Tip#4
Tip#4TheOptimization
TheOptimization
GameGame
Energy
Energy--FracFracGeometry&
Geometry&
improvedPlacement
improvedPlacement
CleanerFluids
CleanerFluidsConductivity
ConductivityProduct
ionOptimization
ProductionOptimization
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Oriented Fracturing Summary Job Results
Reduced excess near-wellbore pressures
Lower treatment pressures & HHP requirements Increased percentage of open perforations (calculated)
Alignment along PFP
Reduced costs compared to oriented TCP
Performance (Conductivity)
Able to pump larger proppant sizes
Allows use of cleaner fluids (VES)
Historical Performance Minimum wellbore deviation of 0.13
Perforations within +/- 5 of the designed placement
Not a single Screenout
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SPE 71652SPE 71652SPE 71652SPE 71652
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($1,500,000)
($1,000,000)
($500,000)
$0
$500,000
$1,000,000
$1,500,000
$2,000,000
$2,500,000
$3,000,000
$3,500,000
0 90 180 270 360 450 540 630 720
Production Time
NPV-
$$
product ion product ion product ion product ion
Economics
Can well costs be furtherreduced? How much 5-10%?
Optimization Scenarios Costs and performance
Financial upside
How about the Productionupside?
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Financial Perspective
Probability of success Productivity Increase
Improved Total Well SystemEconomics
Accelerated Payout
Improved ROI Incremental Cash Flow
Frequency Chart
Certainty is 50.00% from 53.62% to 102.33% %
.000
.004
.007
.011
.015
0
18.25
36.5
54.75
73
2.70% 42.14% 81.59% 121.04% 160.48%
5,000 Trials 1 Outlier
Incremental Economics @ Year 1
Conventional Scenario 1 Scenario 2 Scenario 3
$110,000 750,000 900,000 $1,200,000 Incremental NPV @ Year 1
13.54% 85.07% 89.92% 103.84% ROI @ Year 1
310 - 365 170 165 152 PayOut Time Days10 - 12 5.6 5.4 5.0 PayOut Time Months
Tip #5Tip #5
Will it workfor my well?Will it workfor my well?
Not significant CostincreaseNot significant Costincrease
Doyour homeworkDoyour homework
Not for every wellNot for every well
Not without the dataNot without the data
Check the reservoirpotentialCheck the reservoirpotential
deliverabilitydeliverability
ROI is king!!!ROI is king!!!
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SPE 71652SPE 71652SPE 71652SPE 71652
2001 ATCE2001 ATCE2001 ATCE2001 ATCE New OrleansNew OrleansNew OrleansNew Orleans
Conclusions Having all perforations aligned along
the PFP and directly open to the
fracture, the energy is focused on
optimal placement and creating the
fracture geometry rather than fighting
near-wellbore effects
GeoMechanical model allows forintegration of reservoir and rock
mechanics into optimum fracture
treatment design (OF and
conventional)
OF allows for higher concentrations forimproved conductivityconductivityconductivityconductivityand production
response
Completion scenarios are investigated todetermine the perforating/fracturing
strategies for
Optimum fracture placement
Increased production and,
Maximum ROI, ROA