PowerSTIMWell optimization service

The oil and gas industry is constantly evolving;

we are always looking for a better way to get the

job done. The best tools and methods are the

ones that fit your business needs. That is why we

develop solutions with you—not just for you.

Your local knowledge is combined with our

multidisciplinary industry expertise and the

most advanced technologies in the business.

Together, our combined team develops work-

flows that fit wherever you need them, anywhere

in the world, resulting in decisions that work for

your bottom line.

find theapproachthat works >>

>> together we can

Need for stimulation optimization Stimulation is a major expense in many well completions. Each year more than 20,000 wellsworldwide are hydraulically fractured. At a costexceeding $2 billion—an average of $100,000 perwell—the results often barely justify the expense.

It is estimated that two-thirds of these wells donot respond as expected and fail to meet objectives,and that fewer than 1% of fracturing treatments areoptimized to maximize production and recovery.Instead, the tendency is to rely on acid or proppantfracturing treatments that have always been per-formed the same way in a particular area—the one-size-fits-all approach—or to base treatments on estimates of average reservoir properties, whichmay result in hydraulic fractures of insufficientlength and width with excessive vertical height.

Service optimizes treatments The PowerSTIM* well optimization service takes afit-for-purpose solution-oriented approach that hasproved effective in a broad range of reservoir types.Stimulation treatment design and execution are customized to the specific conditions in the well orfield, based on detailed, accurate formation evalua-tion and modeling by a multidisciplinary team ofclient and Schlumberger experts. Based on thePowerSTIM team's analysis, treatment options suchas acid treatments, fracture treatments, or sandmanagement will be considered. The knowledgegained from each stimulation treatment is used to improve the next, in a continuous, closed-loopprocess that reduces costs, maximizes productionand increases recovery.

Turning reservoir specifics intostimulation solutions

PowerSTIMWell optimization service

Applications

■ Optimizing profitability in both high-productivity conventional reservoirs and low-permeability heterogeneous, layered reservoirs

■ Improving performance of marginal fields

■ Overcoming completion problems or failures

■ Reengineering completions to maintain orexceed past production at economicallyjustifiable costs

Benefits

■ Increased production

■ Improved profitability

■ Greater return on stimulation investment

■ Reduced completion and production costs

■ Shorter learning curve over fewer wells

■ Greater understanding of well performance

■ Access to Schlumberger experts worldwide

■ Knowledge gained for improving future wells

Features

■ Proprietary workflow process

■ Multidisciplinary team

■ Real-time monitoring and communication

■ Integration of best-in-class Schlumberger services

■ Value creation through collaboration

■ Continually updated informed decision report(IDR)

■ Basin-specific reservoir and completion models

■ Advanced software programs for stimulation optimization

The first step in the PowerSTIM process is forming theteam, which normally is made up of geoscientists, reser-voir and production engineers, and stimulation designers.Initially, the team concentrates on a small group ofwells—typically three to five, depending on field andreservoir complexity.

After collecting and analyzing all available data, theteam uses the information to build a customized modelthat describes geology and reservoir dynamics. Thismodel, which accurately predicts key parameters andforecasts production, is used to design optimized treat-ments for the first group of wells.

Geologic considerations■ Review log and core data

■ Understand effects of depositional, structural and stratigraphic models

Reservoir considerations■ Apply improved reservoir

profiles (e.g., stress, perme-ability, oil, gas, water)

■ Provide improved 3D data setfor stimulation design

■ Finalize prefracture reservoircharacterization

■ Design and analyze pressurebuildup test

■ Analyze production data (pressure and rate)

■ Material balance

■ Make performance forecasts

Geologic considerations■ Review depositional envi-

ronment

■ Review structure andstratigraphy

■ Review geological model

■ Develop local interpreta-tion models

Reservoir considerations■ Review offset well data

■ Understand reservoir performance

■ Improve reservoir profiles (e.g., stress, permeability)

■ Develop Mechanical EarthModel (MEM)

The PowerSTIM process >>

PowerSTIM elements

Well analysis

Select treatment■ Perforation optimization

■ Matrix acid

■ Acid or proppant fracture

■ Sand or water management

■ Well architecture

Completion design■ Recommend perforation

interval

■ Design DataFRAC* services

■ Optimize casing and tubulars

■ Revise performance forecast

■ Design production or artificiallift systems

■ Evaluate technology options

Treatment selection and completion designField data review

10450

10400

10500

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10500

10450

10400

10500

Processed Logs - Elan, FracHITE

if economically justified.

Objective

Date:

Well Location:

Elevations:

API Number:

Contact: Name:

KB:

DF:GL:

Company:

Well Name:

Field:County:

State:Sample IDR

AnyAllJack

Completions & Production Solutions

PowerSTIM IDR - Informed Decision Report

Email:

Phone:

The objective of this PowerSTIM project is to assess the current

completion effectiveness. Production results against the reservoir model

forecasts indicate that the design parameters for fracture conductivity

and fracture half length are not being met.

Objective

< 0.0 md.ft0.0 - 165.0 md.ft165.0 - 329.9 md.ft329.9 - 494.9 md.ft494.9 - 659.9 md.ft659.9 - 824.8 md.ft824.8 - 989.8 md.ft989.8 - 1154 7 md f

Treatment analysis■ Analyze post-treatment data

■ Perform post-treatment production data analysis

■ Design and analyze post-treatment pressure transienttest

■ Update reservoir and completion model

Optimization■ Incorporate results into next

completion design

■ Improve reservoir and completion model accuracy

■ Reduce cycle time and wellcosts

■ Optimize production

Analysis and optimization

Treatment design■ Run appropriate laboratory

tests

■ Use improved reservoir profiles

■ Use CADE software suite

■ Calculate net present values(NPVs) of design options

■ Optimize stimulation

■ Use interpretation models andexpertise

On-site execution■ Perform quality assurance and

quality control

■ Ensure design criteria are met

■ Supervise implementation of pumping schedule

■ Analyze diagnostic tests

■ Monitor job in real-time

Stimulation designand execution

After these treatments are executed according todesign, the PowerSTIM team evaluates the results anduses them to update the model, which is then used tooptimize the next group of completions. The updatedmodel often is available to decision-makers within afew hours after the evaluation is finished.

Performance driven >>

Schlumberger innovations are major contributors to the timeli-ness, efficiency and success of thePowerSTIM process. One of theseinnovations is the PowerSTIM “in-time” report, or IDR, which docu-ments the PowerSTIM solution andprovides a complete, historicalrecord for each well treated.Another is the InterACT* real-timemonitoring and data delivery, whichfacilitates collaboration and allowsreal-time monitoring of treatments.

InterACT system The InterACT system promotesteamwork by providing Web-baseddata delivery with secure real-time,two-way communication at all stagesof the project—from initiation topost-job analysis. Files of all stan-dard data types and formats can beexchanged and shared, and stimula-tion operations can be monitored

and supervised in real time fromremote locations, resulting in betterwell treatments. Integration of theInterACT system with the FracCAT*fracturing computer-aided treatmentsystem provides a powerful platformfor the PowerSTIM process.

Updated report The comprehensive IDR is builtdynamically on a personal computerdesktop. As the project proceeds,the PowerSTIM team continuallyupdates the report, which beginswith the initial reservoir charac-terization and progresses throughcompletion design and execution to postjob evaluation, recommenda-tions and summary.

At any stage in the project, thereport can be viewed via the InterACTsystem or printed as a hard-copysnapshot, similar to a well log, forquick access to well information.

Whether viewed on paper or onscreen, the report facilitates collab-oration. It is a tangible representa-tion of the value inherent in thePowerSTIM process and is usuallydelivered cumulatively in threestages: ■ well and reservoir characterization

■ design

■ execution, evaluation and summary.

Comprehensive data set PowerSTIM optimization is based on a comprehensive data set andcomplete reservoir characteriza-tion—not standard correlations,averages, estimates or assumptionsabout reservoir performance param-eters. The data set, which includesrock mechanical properties, hydro-carbon-resource profiles and sand-prediction models, is used for well-performance forecasting, reservoirsimulation and well-completiondesign.

Basin-specific models The PowerSTIM team builds basin-specific petrophysical and comple-tion models to predict and optimizethe effects of stimulation treatments.These models provide key parame-ters such as net pay, producible fluids, permeability, porosity, fluidsaturation, magnitude and directionof tectonic stresses, and other rockmechanical properties.

Innovations facilitate process >>

At any stage in the project,the report can be viewedvia the InterACT system…

Initially, the models are developedfrom local knowledge, data fromprevious completions in offset wellsand existing reservoir models. Themodels are updated with new infor-mation as it becomes available, andadditional data required to ensuremodel accuracy are acquired by log-ging, testing or sidewall coring ofthe candidate wells.

Geological model for planning Petrophysical and mechanical properties are usually merged in ageological model, which is used toplan initial strategies for the com-pletion design. ELANPlus* softwarefor elemental log analysis is used todevelop this model, and some para-meters may be calibrated againstexisting core data or sidewall cores.Analyses from offset wells also areused in finalizing the geologicalcharacterization.

Formation evaluation technology The PowerSTIM team uses a widerange of technology to collect dataneeded to quantify reservoir parame-ters and improve models. Porosity

and permeability measurementsfrom a CMR-Plus* CombinableMagnetic Resonance logging toolwith high-logging-speed capability,along with mechanical propertiesfrom DSI* Dipole Shear SonicImager logs, are used to improvestimulation candidate selection.

Permeability derived from CMR-Plus measurements also canbe used to determine leakoff anddesign fracture stimulations, andDSI compressional and shear dataare used to derive Young’s modulusand Poisson’s ratio. The CHFR*Cased Hole Formation Resistivitytool can identify fluid saturations in cased wells, and FMI* FullboreFormation MicroImager micro-resistivity images help identify faultplanes and preferred fracture planeorientation.

Completion and treatment design The PowerSTIM team designs a customized completion based on all available well data. This design is focused on maximizing produc-tion for the lowest cost and includesrecommendations on perforation

interval, tubular optimization andstimulation treatment. Integration of all available basin, field, reservoirand well data for better evaluationof formation characteristics facili-tates optimization of fracturingfluids, proppants and volumes.

Stimulation design technology The stimulation design is optimizedusing advanced software programs.Petrophysical data are distributedinto reservoir layers for fracturemodeling with a zone-by-zone layer-ing program or FracCADE* fractur-ing design and evaluation software.FracCADE software also predictsfracture geometry, using formationparameters such as shear modulus,Young’s modulus, Poisson’s ratio,permeability, overburden stress and pressure.

Visualization software provides a “picture” of fracture geometry, orientation and barriers. In-situtests, including minifracture treat-ments using the DataFRAC fracturedata determination service, providecorrelations to complement and verify empirically derived values.

The Production Data FractureInterpretation Tool determines fracture half-length and conductivityand the effective permeability ofstimulated formations. Production is correctly allocated to each com-pleted interval using production log data, and NODAL* productionsystem analysis evaluates well pro-ductivity, taking the completiondesign into account.

The PowerSTIM teamdesigns a customizedcompletion based onall available well data.

Sidewall-cores corrected fornet overburden

Porosity

Neutron porosity

vol/vol0.3 0.0Density porosity

vol/vol0.3 0.0Total CMR porosity

Crossover CMR free fluid

Highporosity

Highporosity

Lowporosity

vol/vol0.3 0.0

Free fluid CMR permeability, mD

Density porosityvol/vol0.3 0.0

CMR bound fluidvol/vol0.3 0.0

StandardTimur-Coates equation0.002 20.0

Lobo-specificTimur-Coates equation0.002 20.0

Porosity and permeability do not correlate

Accurate and reliable permeability log profiles are key to production optimization. A Timur-Coatesequation modified specifically for the Lobo formation provides a better core-log correlation in thisexample. It provides an improved permeability profile for stimulation design in the Lobo formation.

Perforation strategy The PowerSTIM team devises a per-foration strategy that helps achievethe desired fracture properties. Thisstrategy may include using high-per-formance UltraJet* deep penetratingshaped charges to increase forma-tion penetration and orienting theperforations to encourage hydraulicfractures to follow the direction of natural stresses. Orienting theperforating guns with the WirelineOriented Perforating Tool allowsfracture design to be focused on

fracture placement instead of prop-pant transport. Oriented perfora-tions minimize the risk that near-wellbore complexities or tortuositywill cause premature screenout.

Stimulation execution and evaluation PowerSTIM treatments are executedwith an emphasis on diagnosis, qual-ity assurance and quality control, andreducing cycle time. Following thetreatments, production logs, temper-ature logs, tracer logs and otherdata are acquired and analyzed.

Actual production is comparedwith the forecast made prior totreatment. If there is a gap, allavailable mechanical and petro-physical data are used to refinethe fracture designs and updatemodels to improve results fromthe next treatment.

Closing the loop The last step of the PowerSTIMprocess is closing the optimizationloop by presenting a complete jobsummary, which is documented in the IDR. This summary includes recommendations and a go-forwardplan for future wells.

Collaboration creates value In the PowerSTIM process, clientreservoir knowledge and field expe-rience and Schlumberger technologyand expertise work together to cre-ate value. This close collaborationreduces engineering cycle time byexpediting the learning process andresults in selection and applicationof the best stimulation technologiesand completion solutions.

The PowerSTIM IDR is a presentation of logs and graphicsthat depicts a total picture of the process of gathering andinterpreting the data, generating an appropriate solution,implementing the solution and evaluating the results. Theoptimization loop is closed by presenting a complete jobsummary including recommendations and a go-forwardplan for future wells.

The OrientXact* perforating system is an important component of the perforation optimizationpart of the PowerSTIM process.

Reservoirsnapshot >>

0.779

0.695

0.646

0.646

0.646

0.742

0.797

0.714

0.826

0.839

0.28

0.26

0.23

0.23

0.23

0.28

0.29

0.26

0.30

0.31

10450

10400

471 9.6

471 7.8

471 6

471 4.2

471 2.4

471 0.6

470 8.8

470 7

470 5.2

470 3.4

470 1.6

469 9.8

469 8

469 6.2

469 4.4

469 2.6

469 0.8

468 9

468 7.2

468 5.4

468 3.6

468 1.8

468 0

467 8.2

467 6.4

467 4.6

467 2.8

467 1

4.35

4.37

4.66

4.66

4.66

4.31

4.90

4.92

4.45

4.93

0.842

0.758

0.809

0.31

0.28

0.30

10500

4732.2

473 0.4

472 8.6

472 6.8

472 5

472 3.2

472 1.4

471 9.6

4.07

4.58

4.47

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Processed Logs - Elan, FracHITE

Raw Logs -Triple Combo

permeability porosity lithology rock propoerties net stress

correlation resistivity porosity

Objective

Date: Well Location:

Elevations: API Number: Contact: Name:

KB: DF: GL:

Company:Well Name:Field:County: State:

Sample IDRAnyAllJack Texas

Completions & Production SolutionsPowerSTIM IDR - Informed Decision Report

Mike DonovanEmail: donovan1@slb.comPhone: 281-285-1916

The objective of this PowerSTIM project is to assess the current completion effectiveness. Production results against the reservoir model forecasts indicate that the design parameters for fracture conductivity and fracture half length are not being met.

Objective

Transforming data to decisions The PowerSTIM service helpsimprove well-by-well financial per-formance by capturing and takingadvantage of all the downhole infor-mation already being collected.

Instant Web-based access to cross-disciplinary expertise and world-wide data exchange gives decision-makers the timely information theyneed to balance improved well per-formance against treatment cost.

…client reservoir knowledge and

field experience and Schlumberger

technology and expertise work

together to create value.

6500 7500 8500 950 0Stress - psi

10300

10400

10500

10600

10700

Wel

l Dep

th -

ft

-0.3 -0.2 -0.1 -0 0.1 0.2 0.3ACL Width at Wellbore - in

0 500 1000 1500 2000 2500Fracture Half-Length - ft

< 0.0 md.ft

0.0 - 165.0 md.ft

165.0 - 329.9 md.ft

329.9 - 494.9 md.ft

494.9 - 659.9 md.ft

659.9 - 824.8 md.ft

824.8 - 989.8 md.ft

989.8 - 1154.7 md.ft

1154.7 - 1319.7 md.ft

> 1319.7 md.ft

FracCADE*

*Mark of Schlumberger

ACL Fracture Profile and Conductivity

Samson Lone Star LTDPrice #9 Taylor12-18-200 0

Samson ResourcesWell PERFORMance Analysis © 2001

System Graph

Well:Loc:Desc:File: Date:

Price #94920' FEL & 2400' FSL of the E.C. Young Survey; A-879Breaker added - Taylor completion onlyPRIC9_FR.pf3 02-14-2001

Type:Analysis:Node:

Gas WellSystem AnalysisBottomhol e

0 500 1000 1500 20000

1000

2000

3000

4000

Gas Rate, Mscf/D

Pres

sure

, psi

g

Inflow @ Sandface (1)Not Used Inflow (1) Outflow (A) Case 2 (2) Case 2 (B) Case 3 (3) Case 3 (C) Case 4 (4) Case 4 (D) Not Used Not Used Cond Unloading Rate Water Unloading Rate Max Erosional Rate

1

A

1 2 3 4

Inflow

Inflow

Fracture Perm, md

(1) 3000.0000(2) 4000.0000(3) 5000.0000(4) 6000.0000

Reg: Authorized User - Dowell Schlumberger

Case 1 Input DataFluidWater Cut 10.0000 %Oil Grav 40.0 ˚APISG Ga s 0.650GOR/Yield 0.0001 bbl/MMcfSG Water 1.070

Resv - Fractured WellResv BHP 3500. 0 psiaResv Temp 250 ˚FResv Perm 0.0200 mdPorosity 7.5000 %Resv Thick 85 ftResv Ra d 1000 ftTot Compr 3.0300e-004 1/psiaProd Time 24.000 hrsFrac 1/2 Ln 800 ftFrac Perm 3000.0000 mdFrac Widt h 0.100 in

Compl- Open Hol e

Tbg - Cullender & Smith (1956)WH Press 800. 0 psigPerf To p 1040 0 ftCsg ID 4.000 inTbg ID 1.995 in

Flowln - None Calculated

WB Heat - Linear GradientWH Temp 80 ˚F

60 80 100 120 140 160 180 20 0Treatment Time - mi n

2500

3000

3500

4000

4500

5000

Trea

ting

Pres

sure

- ps

i

0

10

20

30

40

50

60

Slurry Rate - bbl/min

0

1

2

3

4

5

6

Prop Conc - PPA

Treatin g Pressure - psi

Slurr y Rate - bbl/min

Pro p Conc - PPA

FracCADE*

*Mark of Schlumberger

Pressure, Rate, Concentration

Samson Lone Star LTDPrice #9 Ta ylor12-18-2000

Sectio n 2: We llbor e C onf igur at io n

Deviat ed Hole NOTr eat Down CASINGFl ush Volume to 10438.0 ft 162. 2 bbl

No Tubing.

Casing Da taOD(in)

Weig ht(lb/ft)

ID(in)

De pt h(ft)

4. 500 11. 6 4 .000 10800. 0

Pe rf or ation Da taTo pMD(ft)

To pTV D(ft)

Bo tto mMD(ft)

Bo tto mTV D(ft)

ShotDe ns it y(shot/f t)

Nu mb er

( )

Di ameter

(in)10438. 0 10438. 0 10445. 0 10445. 0 1 .1 4 8 0. 3010450. 0 10450. 0 10464. 0 10464. 0 1 .0 7 1 5 0 .3 010472. 0 10472. 0 10478. 0 10478. 0 1 .1 7 7 0. 3010528. 0 10528. 0 10532. 0 10532. 0 1 .2 5 5 0. 3010536. 0 10536. 0 10540. 0 10540. 0 1 .2 5 5 0. 3010544. 0 10544. 0 10548. 0 10548. 0 1 .2 5 5 0. 3010558. 0 10558. 0 10562. 0 10562. 0 1 .2 5 5 0. 3010575. 0 10575. 0 10579. 0 10579. 0 1 .2 5 5 0. 3010598. 0 10598. 0 10604. 0 10604. 0 1 .1 7 7 0. 3010616. 0 10616. 0 10620. 0 10620. 0 1 .2 5 5 0. 30

Results Analys is T ype

R es ults T abl eCumulative Rate Average Cumulative Rate Average

k, (md) 0.0378 0.038 5 0. 0381 0.0049 0.0049 0. 0049 xf, (ft) 179.49 174.35 176. 92 395.59 397.06 396. 32

kxf2, (md-ft 2) 1.22E+03 1.17E+03 1. 19E +0 3 772.10 772.07 772. 08

kfbf, (md-ft) 1.17E+01 1.16E+01 1. 17E +0 1 6.61 6.50 6. 55

k(k fbf)2, (md 3-ft2) 5.22 5.19 5. 20 0.22 0.21 0. 21

l , (md/cp) 1.76E+00 1.79E+00 1. 77E +0 0 0.229 0.227 0. 228 l xf

2, (md-ft 2/cp) 5.66E+04 5.43E+04 5. 54E +0 4 35858.3 35856.7 35857. 5 l (kfbf)

2, (md 3-ft2/cp) 242.4 240.9 241. 7 10.0 9.6 9. 8 k fbf/xf (md-ft/ft) 0.065 0.067 0. 066 0.017 0.016 0. 017

Fc d 1.73 1.73 1. 73 3.39 3.34 3. 36

Estimated: Perm, (md) 0. 0049 xf, (ft) 396. 32 F cd 3. 36

Theoretical tstart (days) 100.87 100.8 7Graphical tstart (days) 108.00 108.00Theoretical tend (days) 46.84 46.84 173.51 173.51Graphical tend (days) 19.25 19.25 177.59 177.59

C o ns is tency C h ecks

Bilinear Flow Formation Linear Flow

0 100 200 300 400 500 600 700

Time (days)

0

500

1000

1500

2000

Rate

qo (STB/D)qg (Mscf/D)qw (STB/D)qo Data (STB/D)qg D ata (Mscf/D)qw Data (STB/D )

ProCADE*Single Layer Forecast: Rates vs Time

K=0.0031 mdXf = 476 ft.Conductivity = 33.6 md-ft

The use of PSPLitr, ProFIT, ProCADE, proved extremely valuable insuccessfully modeling production behaviour in comingled,multi-stage wells.

Once a production match was achieved on multiple wells, themodel was verified. Confidence in the model and hydraulic fracturecharacterization allowed the modeling of improved design consider-ations, one of those being the addition of breakers to improvefracture conductivity.

Further improvements to the existing design(s) are being exploredand will be suggested if economically justified.

There are still several areas to examine in the process ofproduction and stimulation optimization. One such opportunity is toreduce the degradation of fracture conductivity due to multi-phaseflow. This may be especially true in the Upper Cotton Valley interval.Improved reservoir characterization is the key to properlyaddressing this issue.

The performance of the well will be monitored for 6-12 months.Several different and independent types of analysis will be used to assess the impact of implementing the encapsulated breaker design.One robust form of analysis includes the continued use of ProFITand ProCADE.

Summary

Recommendations

XX400

XX500

XX600

MDft

XX300

XX200

GRPass 2

API0 200 0 lbm/ft2 6

GR

Fracturewidth, in.

TotalScandium

TotalIridium

Cased-hole

Sandconcentration Formation

Scandium

Iridium

Formation

Scandium Scandium Iridium

Iridium

PowerSTIM teams often have to evaluate multiple zone scenarios to determinewhich strategy results in maximum production for the lowest cost. This radio-active survey indicates successful placement of two separate fractures lessthan 100 ft apart.

FracCADE and StimCADE software FracCADE and StimCADE* software allows evalua-tion of different strategies to better understand howthey will impact fracture geometry. Issues such asconnectivity to the perforations, height growth, frac-ture length, bridging and conductivity are consideredin this evaluation.

Schlumberger visualization software allows thePowerSTIM team to “see” the impact of fracturegeometry and its relation to reservoir size and orien-tation. This visualization is useful in building a strat-egy to optimize the completion and overallproduction.

FracCADE LG Zones module A unique zone-by-zone layering routine identifies and evaluates individual zones in a layered formation.This analysis tool is a critical link between formationevaluation data and the FracCADE program.

ProFIT* softwareProduction-data analysis using the Production DataFracture Interpretation Tool program determines fracture half-length and conductivity and the effectivepermeability of stimulated formations without shut-ting wells in for analysis. Schlumberger is the onlycompany that provides this evaluation service.

Production allocation program Production log data are used as input to correctly allocate production to each completed interval incommingled, multilayer reservoirs. This allocationprogram allows determination of maximum perme-ability, minimum fracture length and conductivity for each zone.

NODAL analysis NODAL analysis is used to evaluate well productivity,taking perforations, tubulars and surface facilitiesinto consideration. Each pressure interface is treatedas a node with several variables.

IDR The hard copy of the IDR is made up of 81⁄2-in. by 14-in. pages that fold out. Well location andrelevant background data are shown on thecover. Inside, a section of mud log or openholelog, core analysis and other test data identifypertinent zones. A wellbore configuration showsthe completion design and perforation record.

The execution section documents the stimu-lation design and implementation and oftenincludes prefracture diagnostics plots and thethree-parameter plot of the treatment. Additionalsections present stimulation designs, productivityanalyses, production forecasts and logs, andactual production data.

Reservoir profilesNuclear magnetic resonance (NMR) technologyis used in the CMR-Plus tool, which exciteshydrogen nuclei in formations by setting up a magnetic moment, relaxing it and measuringthe time it takes atoms to realign. This NMRrelaxation time is dependent on pore size andporosity, which is related to permeability.

Stress profilesThe DSI sonic tool excites formations withacoustic waves and measures the resulting compressional and shear transit times. Transittimes are converted into rock properties such as shear modulus, Young’s modulus andPoisson’s ratio.

Shear modulus is an elastic material constantthat is the ratio of shear stress to shear strain.Young’s modulus is an elastic material constantthat is the ratio of longitudinal stress to longitu-dinal strain. Poisson’s ratio is an elastic constantthat is the ratio of latitudinal to longitudinalstrain, or a measure of material compressibilityperpendicular to applied stress, that can beexpressed in terms of measured properties,including compressional- and shear-wave velocities.

Transform data to decisions >>

POCKET

To learn more about stimulation solutions

and PowerSTIM well optimization services,

visit www.slb.com/oilfield and select

Stimulation or e-mail powerstim@slb.com.

ST_03_005_0 ©Schlumberger

October 2003 *Mark of Schlumberger

www.slb.com/oilfield

PowerSTIMWell optimization service

To learn more about stimulation solutions

and PowerSTIM well optimization services,

visit www.slb.com/oilfield and select

Stimulation or e-mail powerstim@slb.com.