Oriented Fracturing

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Oriented Fracturing A Practical Technique for

Production Optimization

F. Fragachan

Schlumberger Oilfield Services


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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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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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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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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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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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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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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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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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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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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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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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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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($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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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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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

Documents

Oriented Fracturing