Coiled Tubing

ABSTRACT

The implementation of extended reach horizontal wells inSaudi Arabia, in the southern area of the Ghawar field inparticular, is being increased for production and costoptimization. Logging these wells is a challenge, as theproduction profile of a horizontal section cannot be entirelyrecorded with conventional coiled tubing (CT). This is mainlybecause of friction forces between the CT and the wellbore,which cause the CT to lockup significantly shallower than thetotal depth (TD). Even with the availability of a limitedtechnique, such as a metal to metal friction reducer, it wasfound that the CT reach cannot be maximized effectively.

This article will describe successful utilization of an agitatortool with a custom designed e-line bypass that helps the CTmaximize the coverage of the horizontal section for loggingpurposes. The agitator tool was incorporated into theProduction Logging Tool (PLT) and bottom-hole assembly(BHA). It was activated by pumping. It caused the CT stringto vibrate and subsequently reduce the friction contactbetween the CT and the wellbore to allow the CT to runbeyond the normal lockup depth.

The tool was trial tested in an extended reach horizontalwell, with a TD of 12,118 ft. The simulator showed apredicted lock at 10,400 ft while a dummy run locked up at10,800 ft without activating the agitator. The e-line agitatorwas activated while the well was flowing at a restricted rate,which maximized the reach to the TD and reduced the frictioncoefficient by around 26%. Different conditions andparameters were applied to understand the best performanceof the e-line agitator tool.

The implementation of the e-line agitator resulted in extendingthe reach of the CT by an additional 1,300 ft and reaching TD.This additional reach was significant, as the last part of thehorizontal section was contributing water. The production log hasbeen reviewed and shows acceptable measurements. This articlewill cover the whole cycle of candidate selection, job design,execution, post job evaluation, lessons learned and conclusion.

INTRODUCTION

Drilling strategy has shifted from vertical to horizontal wellsat most oil fields in Saudi Arabia due to their provenadvantages in optimizing production and cost. Even the

existing vertical wells are being converted to horizontal toprolong their life, improve their productivity index and delaywater encroachment. Furthermore, the drilling strategy isbeing developed by drilling more complex wells, such asextended reach horizontal wells, to maximize reservoircontact. These types of wells are widely implemented in SaudiArabia, particularly in the Haradh area, which is located atthe southern part of the giant Ghawar field.

The extended reach horizontal well can be defined as a wellwith a measured depth (MD) to true vertical depth (TVD) ratiothat is equal to or greater than 2 MD/TVD1, 2. For this particularfield, the horizontal well can be considered an extended reachwhen its horizontal section is equal to or more than 6,000 ft.These wells are a challenge for most of the rigless well inter -vention operations, such as acid treatment and logging, whichuse conventional coiled tubing (CT). The challenge comes fromthe CTs inability to cover the entire long horizontal section.

Due to well architecture, the most common CT size is 2,while sometimes 238 CT is utilized when possible. Thelimitation of CT in long horizontal wells is that it locks upshallower than total depth (TD). This is because the axialcompressive/surface force (Fs) cannot overcome the axialbottom force (Fb) during the run in hole (RIH), caused byfriction forces when the CT buckles into a helical shape1, Fig. 1. To reduce the impact of the friction contact, there arelimited techniques that increase CT reach, such as a metal tometal friction reducer, and a CT tractor3-5. Application of ametal to metal friction reducer could extend the reach for afew hundred feet in this particular field, based on historicalapplications3, 4. On the other hand, while the CT tractor is avery good application for acid stimulation jobs, it is notcurrently applicable for logging operations.

The agitator tool offers an alternative technique that can beactivated hydraulically from the surface by pumping water.The main function of an agitator is to create vibrations thatreduce the surface contact of the CT string with the wellbore.This type of motion creates a significant reduction in frictionforce acting against the CT string while RIH and delays thehelical buckling accordingly.

So far, the agitator has been utilized only for treatmentpurposes at formations with various friction coefficient (FC)values, which showed reasonable results. It was not applicablefor the logging operation, as the wireline needs to bypass the

60 SPRING 2010 SAUDI ARAMCO JOURNAL OF TECHNOLOGY

Maximizing Coiled Tubing Reach duringLogging of Extended Horizontal Wells Using E-line Agitator

Authors: Muhammad H. Al-Buali, Alla A. Dashash, Alaa S. Shawly, Walid K. Al-Guraini, Saad M. Al-Driweesh, Vsevolod Bugrov and Scott Nicoll

agitator to reach the bottom-hole assembly (BHA) andsurveillance tool. This was always a concern from oilcompanies to service providers, to enhance services byproviding an adequate tool, which would act as an agitatorduring the logging operation. Reaching TD while logging isvery important, as it was noted from the previous logs that asignificant amount of water and oil is produced from the lastsegment of the horizontal section.

In response, a custom designed e-line bypass agitator toolwas provided for testing. This article will shed light on trialtesting the tool, which was imple mented in one of theextended reach horizontal wells in the Haradh field.

E-LINE AGITATOR DESCRIPTION AND MECHANISM

The agitator consists of a Positive Displacement Motor (PDM)section, with an upper valve plate attached to the rotor, Fig. 2.The plate has an eccentric hole, and flow is directed through thishole. The rotor causes the plate to oscillate when flow passesthrough the tool. This plate moves above a static plate with ahole. The oscillating plate changes the flow area and createspressure pulses that excite the CT to vibrate and break staticfriction, Fig. 3. The pressure pulse amplitude is directly related tothe flow rate and the weight of the fluid being pumped6.

The agitator has been modified to allow the e-line wire tobypass it to the BHA. The e-line bypass consists of:

A top sub that screws into the upper bulkhead, andconnects to the upper BHA.

The upper bulkhead that houses the packing stackelement and is also used to anchor the wireline whenrequired.

The wireline, which runs in the annulus between theagitator and the outer sleeve.

The downhole agitator.

The lower bulkhead that returns the wireline back intothe flow path.

The bottom sub that also retains the sleeve and connectsto the lower BHA, Fig. 4.

CASE COMPLETION AND HISTORY

Well A was drilled as an extended reach horizontal well acrossa carbonate formation in the Haradh area. The 618 open holewas drilled to a TD of 12,118 ft MD at around 6,090 ft TVD

SAUDI ARAMCO JOURNAL OF TECHNOLOGY SPRING 2010 61

Fig. 1. Axial surface force vs. axial bottom force.

Fig. 4. E-line agitator schematic.

Fig. 2. Agitator cross section.

Fig. 3. The impact of the flow rate area on pressure.


temperature, gamma ray, casing casing locator (CCL), X - Ycaliper, fluid hold-up, full bore spinner (FBS) and fluid flowlogging tools and an approved tool for wet well productionlogging that could detect the water entry zone. The log wasneeded to decide on a remedial action to maintain wellproductivity. Logically, maintaining well productivity couldbe achieved with the utmost information gained from thewellbore. Based on that, different remedial action techniquescan be applied depending on the identified water productionzones (heel, middle or toe). It was expected that water wasbeing produced from the bottom zone (toe); trajectory andazimuth values also indicated that the well was drilledtoward the injection boundary. Accordingly, the objective ofthe job was to convey the logging tool to the TD to capturethe flow profile across the entire horizontal section.

WELL INTERVENTION SIMULATION

It is a common practice to run well intervention simulations formost of the CT intervention jobs to establish the CT reach andthe CT working limit so that the CT size can be determined.Each service provider has its own software, and results willdepend on the reliability of the entered data.

The simulation predicted a lockup depth, in the case of 2CT based on actual field data. The most important parameterconsidered was the open hole FC during CT RIH. Theproposed FC values of 0.43 and 0.4 represented the worst andbest case scenarios, respectfully. Both simulations showed thatan early lockup depth would occur at 9,980 ft MD and10,485 ft MD, respectively, Fig. 6. Additionally, the simulatorwas then utilized to predict a 238 CT lockup, which showed aminor advantage. Finally, the simulator was utilized to predictthe lockup of the 2 and 238 CT with the help of an agitator,which showed a complete reach to the TD, Fig. 7.

CHALLENGES

The main objective of this job was to reach TD and collecthigh quality data. Although operations have had very goodexperience in deploying the agitator for acid stimulationpurposes, use of this tool in a logging operation presentedadditional challenges. These are due to the following:

with a maximum dogleg severity of 7 degrees/100 ft. The firstkickoff point (KOP) is started from 4,600 ft MD while thesecond KOP is started from 5,803 ft MD. The 7 liner was setat 6,768 ft MD while the end of tubing (EOT) depth is 6,929ft MD. The well was completed with a 7 big bore packer and4 tubing with a minimum restriction of 3.725, Fig. 5.

Initially, the well produced dry oil at a restricted chokesetting. Almost two years later, the well started to cut water,which gradually increased even with more restriction. Severalsurface production tests and collected wellhead sample resultsshowed that the water production had increased up to 8%water cut while salt concentration was more than 1,500pounds per thousand barrels (PTB).

OBJECTIVE

A production log was required to record the productionprofile of the horizontal section and detect the water entryzone. The logging tools that needed to be run were pressure,

Fig. 5. Well A cross section schematic.

Fig. 6. Simulator results without agitator.

Killing the Well

In acid stimulation jobs, the agitator is activated using wateras it makes it perform aggressively. Consequently, duringlogging operations, pumping a large volume of water in thewell could cease the well to flow, so no measurements couldbe obtained during flowing passes. Even the log during shut-incondition would not be representative as the well would beoverbalanced.

Snubbing Force

RIH during logging operations is not only at shut-incondition, as is the case with acid stimulation. The well needsto be flowed during RIH for better logging measurement. Thisadds another force against the CT, along with friction contactforce, which is known as a snubbing force. Accordingly, thisforce will alleviate the agitator performance and it is expectedthat the CT will lockup at a shallower point during flowingcondition than at a shut-in condition.

Maintaining CT Optimum Speed

As per the experience with acid stimulation jobs, the CT isrun at very low speed, which could not be kept constant basedon the agitator and CT weight performance. This conflictswith the common practice during logging operation, whichrequires RIH while maintaining the optimum running speedfor reliability of the logging measurement.

Pumped Volume

The pumped fluid volume to activate the agitator is always achallenge due to cost and logistics.

JOB PLANNING

Several discussions were held with a multidisciplinary teaminvolving production engineers, a logging company, a CTcompany and an agitator service provider to determine aneffective logging design to enable reaching TD while ensuringlogging effectiveness at an optimized cost. First, it was decidedto utilize a 2 CT rather than 238, as the simulator indicatedthe 2 CT could reach TD with the help of an agitator tool,

to optimize the operational cost. The second decision was todeploy a 314 e-line agitator, based on the given parameters.

The above challenges were thoroughly discussed and agroup of mitigation solutions was formulated. Regarding thefirst challenge, it was agreed to pump diesel rather than watersince it has a lower density. This would make only a smalldifference in the optimum performance of the tool, whichcould be compensated for by a higher pumping rate. Waterwould be utilized during the function test only forenvironmental and safety considerations.

Concerning the second challenge, the team planned to flowthe well at a restricted rate to reduce the impact of the highflow. If this case was successful, it was decided to run it againat a higher rate to understand the agitator performance, aswell as the reduced back pressure resulting from chokerestriction to detect if there is water coning. In addition, theteam agreed to activate the tool before lockup, with the goalof preventing early helical buckling. Historically, the agitatorwas activated at the CT lockup depth so the CT could be rundeeper just for a few hundred feet of distance4. The shortextended reach distance is because the CT had alreadyhelically buckled, and subsequently, it was difficult for theagitator to perform as expected.

About the pumped volume challenge, early pumping ofdiesel to TD would require allocating a big volume onlocation to cover the desired interval. The same volume wouldbe needed for the second run at a higher rate and during shut-in condition. The required volume would depend on thepumping rate and speed of the CT. Accordingly, the estimatedcumulative required diesel was around 32,000 gallons.Consequently, a plan was devised to activate the tool at theminimum required rate and then gradually increase it to theoptimum activation rate to optimize the volume.

JOB EXECUTION

The main description of the job execution sequence is asfollows:

1. Pre-job requirements were met and a safety meeting withall involved personnel was held on location.

2. A 2 CT, blowout preventer (BOP), kill lines, etc., were riggedup. The logging head tool was connected to the CT end.

3. Pressure tests were conducted as per Saudi Aramcorequirements.

4. A 314 e-line agitator was connected and then functiontested. All rates and pressure values were recorded whilethe optimum pumping rate was verified, Table 1.

5. A 36 ft dummy tool, equivalent to the actual logging toolsdimension, was hooked up to the e-line agitator.

6. The CT with the dummy tool was RIH while the well wasshut-in to ensure tool accessibility through minimumrestriction and to ensure no obstruction would beencountered. At this stage, the e-line agitator was not


Fig. 7. Simulator results with agitator.


indicate any slack off signs of hitting any mechanicalobstructions, which confirmed lockup occurrence. Thisdummy run was representative of lockup depth during theactual logging run as the difference between the dummy runand logging run was the BHA.

Figure 8 also illustrates the actual weight encountered in thejob; the blue line indicates the RIH simulated weight. Aftercompleting the first run, the FC value of the open hole wasupdated to accurately match the simulation to the actualweight. Since the CT locked up during RIH in the open hole,the original FC (0.43 or 0.4) of the open hole was notestimated accurately. Consequently, by extrapolating from thetrend obtained at the beginning of the open hole, the originalFC in the open hole was estimated to be 0.38; therefore thelockup depth would have been at 10,800 ft. Weight fluctuationsbefore the lockup point are common and can be explained bythe shape of the CT string inside the wellbore. First, the CTstring takes a sinusoidal shape, and when friction force exceedsa certain value (helical buckling load), the CT becomes helicallybuckled and the contact area between the CT surface andwellbore walls significantly increases. Still, the CT string has amovement momentum which allows it to penetrate deeper, butat the lockup point, the friction force exceeds the CT weight,and the CT becomes compressed and cannot be pushed deeper.

Logging Run at Flowing Condition and Restricted Rate

In this stage, the CT was run with the logging tool while thewell was flowing at a restricted rate to record the flow profile.The CCL was part of the logging tool as it is necessary for thelogging operation to determine accurate flow zone depths. Thee-line agitator was activated by pumping diesel, starting from45 degrees of the wells inclination. The volume of pumpeddiesel was approximately 8,000 gallons at 1.0 barrel per minute(bbl/min). Figure 9 shows the CT reached the TD at anoptimum speed of 25 ft/min while the entire open hole sectionwas logged.

Figure 10 shows the actual weight encountered in the job;the blue line indicates the RIH simulated weight. The FC inthe open hole was calculated to match the lockup depth whilekeeping the same FC in the tubing. It was found that onlywhen the FC is decreased to 0.28, is CT able to reach thatdepth. As a result, the FC was decreased by 26% from 0.38 to0.28, assuming the agitator had an effect on the open hole

activated to determine the actual lockup depth, if it were tooccur. After that, the CT was pulled out of hole (POOH).

7. On the surface, the dummy tool was disassembled andreplaced by actual logging tools.

8. Meanwhile, the well was lined up to the surface test trap tobe tested during the flowing passes to ensure data quality.

9. The CT was RIH while the well was flowing at a stabilizedcondition of a restricted rate. The agitator was activatedusing diesel, starting from 45 degrees of the wellsinclination, and then the well was logged down and up.

10. The CT was RIH again while the well was flowing at astabilized higher rate. The agitator was activated usingdiesel, starting from 45 degrees of the wells inclination,and then the well was logged again down and up.

11. With the well shut-in, the CT was RIH and the well waslogged down and up.

12. The CT was POOH, and the logging tools and e-lineagitator were visually inspected.

RESULTS

The operation was conducted safely and successfully for aperiod of five consecutive days. The results were encouragingand showed that the agitator was functioning within anacceptable performance. The main results that were achieved aresummarized here.

Dummy Run at Shut-in Condition

In this case, the dummy tool was run along with CCL tocorrelate the depth and ensure an accurate lockup point. TheCT passed through all minimum restrictions while nomechanical obstruction was encountered. The CT was runwithout activating the e-line agitator until it reached a depthof around 10,800 ft, which was shallower than TD by almost1,300 ft, Fig. 8. The tension sub and CT weight did not

Table 1. Function test results using water

Flow Rate Circulating Remarks(bbl/min) Pressure (psi)

0.5 700 CT Vibrates0.8 1,300 CT Vibrates Aggressively

Fig. 8. Simulated vs. actual CT weight during shut-in conditions without agitator. Fig. 9. Major operation parameters of the first logging run at a restricted rate.

section only. This value can even be lower as the weightindicator trend is constant and indicates that even if the openhole is deeper than TD, the CT still can RIH deeper in theopen hole with the help of the agitator tool.

2nd Logging Run at Flowing Condition and Higher Rate

The CT was run with the logging tool for the second timewhile the well was flowing at a higher rate. The e-lineagitator was activated by pumping around 1.0 bbl/min ofdiesel starting from 45 degrees of the wells inclination.Figure 11 shows the CT reached a depth of 11,090 ft atfluctuating speed. The volume of pumped diesel wasapproximately 22,000 gallons at 1.0 bbl/min due to speedfluctuation.

Figure 12 shows the FC in the open hole was calculatedto match the lockup depth while keeping the same FC in thetubing. As a result, the FC wasnt decreased and stayed at0.38, assuming the agitator had an effect on the open holesection only. The weight indicator trend was difficult tomaintain, due to snubbing forces against the CT and theagitator that resulted from a high flow rate. The CT speedof 25 ft/min could not be maintained while pumping 1.0bbl/min.

Logging Run at Shut-in Condition

After completing the flowing passes, the well was shut-inuntil it got stabilized. Before the start of this run, it wasnoticed that the diesel volume might not be sufficient to goall the way to TD. A decision was made to go ahead withthe current volume and activated the agitator, if needed,

starting at the lockup depth. Figure 13 shows the CTreached a maximum depth of 12,000 ft, which is 1,000 ftdeeper than the dummy run lockup depth. Taking intoaccount the same friction coefficient value as for the dummyrun, deeper reach of the CT can be explained by pull tests,which were performed periodically during RIH. This allowedthe removal of accumulated buckling from the CT stringwhile POOH.

LOGGING RESULTS

The production profile of the open hole was successfullyrecorded during the three runs. The logging measurementswere properly recorded, and the CT vibration or pumpingdid not adversely affect the results. Figure 14 shows that thewater was produced from the last segment of the open hole.In addition, the log shows the wells complicated geometry,which could be overcome by the agitators performance atflowing condition.

LESSONS LEARNED

This job has added to the experience of performing a loggingoperation using CT with help of an agitator. The main lessonslearned were:

Early activation of the agitator will help delay thehelical buckling and extend the CT reach effectively,even when the well is flowing. This procedure is betterthan activating the agitator at the lockup point orPOOH for a short distance and then activating it.


Fig. 10. Simulated vs. actual CT weight during the first flowing condition at a restricted rate. Fig. 12. Simulated vs. actual CT weight during second flowing condition at a higher rate.

Fig. 11. Major operation parameters of the second logging run at a higher rate. Fig. 13. Major operation parameters during shut-in condition.


all personnel who participated by providing engineering andoperational support during the logging design, execution andevaluation.

REFERENCES

1. Bhalla, K.: Coiled Tubing Extended Reach Technology,SPE paper 30404, presented at the Offshore EuropeConference, Aberdeen, United Kingdom, September 5-8,1995.

2. Beheiri, F.I., Saudi, M.M., Metwally, S.A., et al.:Optimization of Coiled Tubing Interventions to StimulateExtended Reach Water Injection Wells in a Field in SaudiArabia, SPE paper 116843, presented at the Abu DhabiInternational Petroleum Exhibition and Conference, AbuDhabi, U.A.E., November 3-6, 2008.

3. Beheiri, F.I., Al-Mubairik, A.J., Al-Mulhim, A.K., Al-Meshal, F.M., Noguera, J. and Sierra, L.: Optimization ofCoiled Tubing Interventions on Extended Reach OpenHole Completions in a Field in Saudi Arabia, SPE paper116845, presented at the SPE Russian Oil and GasTechnical Conference and Exhibition, Moscow, Russia,October 28-30, 2008.

4. Nasr-El-Din, H.A., Arnaout, I.H., Chesson, J.B. andCawiezel, K.: Novel Techniques for Improved CT Accessand Stimulation in an Extended Reach Well, SPE paper94044, presented at the SPE/ICoTA Coiled TubingConference and Exhibition, The Woodlands, Texas, April12-13, 2005.

5. Al Shehri, A.M., Al-Driweesh, S.M., Al Omari, M. and AlSarakbi, S.: Case History: Application of Coiled TubingTractor to Acid Stimulate Open Hole Extended ReachPower Water Injector Well, SPE paper 110382, presentedat the Asia Pacific Oil and Gas Conference and Exhibition,Jakarta, Indonesia, October 30 - November 1, 2007.

6. Tongs, T., Hinrichs, A., Spickett, R. and Robertson, L.:Ultra Deep Extended Reach Stimulations, SPE paper106874, presented at the SPE/ICoTA Coiled Tubing andWell Intervention Conference and Exhibition, TheWoodlands, Texas, March 20-21, 2007.

Based on the results during the flowing passes, werecommend flowing the well at a restricted rate torecord the flow profile while RIH.

If the well must be produced at a very high rate or awide choke setting, then the agitator can be utilizedwhile the well is restricted or shut-in until the CTreaches TD or locks up at maximum reachable depth.After that, the choke is readjusted to the desired widesetting and wait for stabilization before recording uppass only.

Diesel is an effective fluid to be utilized for the agitatoractivation in logging operations or during treatmentjobs in wells with relatively low reservoir pressure.

A combination of frequent POOH and agitatoractivation could help the CT get deeper, especially inlong extended reach horizontal wells.

CONCLUSIONS

1. The e-line bypass agitator tool can be effectively customdesigned, and it can convey the wire from the end of theCT to the well surveillance tool without causingmechanical damage or interrupting the transferred datawhen vibrating.

2. The e-line agitator helps reduce the open hole FC by atleast 26%.

3. The e-line bypass agitator is recommended for loggingoperations in extended reach wells.

4. The performance of the agitator could be enhanced byimplementing the above lessons learned.

ACKNOWLEDGMENTS

The authors wish to thank Saudi Aramco, Schlumberger andNOV Andergauge management for their support andpermission to present the information contained in this article.Also, we would like to extend our sincere appreciation toHamad Al-Marri and Turki Al-Saadoun for theiradministrative support. Additionally, we would like to thank

Fig. 14. Log results at a restricted rate.


Saad M. Al-Driweesh is a ProductionEngineering General Supervisor in theSouthern Area Production EngineeringDepartment (SAPED), where he isinvolved in gas and oil productionengineering, well completion andstimulation activities. He is mainly

interested in the field of production engineering, productionoptimization and new well completion applications.

In 1988, Saad received his B.S. degree in PetroleumEngineering from King Fahd University of Petroleum andMinerals (KFUPM), Dhahran, Saudi Arabia. He has beenworking with Saudi Aramco for the past 19 years in areasrelated to gas and oil production engineering.

Vsevolod Bugrov received his M.S.degree in Petroleum Engineering in2003 from the Russian StateUniversity of Oil and Gas, Moscow,Russia. After graduation he started hiscareer with Schlumberger as a CoiledTubing Engineer.

He has 6 years of experience in well intervention andstimulation services, including various applications ofcoiled tubing in arctic and desert conditions. Currently, heworks in Udhailiyah providing technical support for theSouthern Area Production Engineering Department(SAPED) Coiled Tubing operations.

Scott Nicoll is a Technical SupportEngineer specializing in Interventionand Coiled Tubing. After completing aModern Apprenticeship in MechanicalEngineering in 2002, he became anAircraft Technician. In 2004, Scottmoved into the manufacture and repair

of Rolls Royce offshore gas turbines. In 2005, he joinedNOV Downhole (formerly Andergauge), and rapidlyadvanced to become a Specialist in intervention and coiledtubing.

BIOGRAPHIES

Muhammad H. Al-Buali joined SaudiAramco in 2002. He is a PetroleumEngineer working in the Southern AreaProduction Engineering Department(SAPED). Muhammad has 7 years ofexperience, mainly in productionoptimization and well intervention.

In 2002, he received his B.S. degree in Applied ChemicalEngineering from King Fahd University of Petroleum andMinerals (KFUPM), Dhahran, Saudi Arabia.

Alla A. Dashash is a Supervisor in theSouthern Area Production EngineeringDepartment (SAPED). He joinedSAPED as a Production Engineer in2003 where he worked in several areasof the giant Ghawar field. In 2008 hejoined the Udhailiyah Reservoir

Management Division for a one year developmentalassignment.

Alla is an active member of the Society of PetroleumEngineers (SPE) and has several published technical papers.He is also a member of the Young Professionals SPE teamin Saudi Arabia.

In 2003 Alla received his B.S. degree in PetroleumEngineering from Louisiana State University, BatonRouge, LA.

Alaa S. Shawly is a PDP ProductionEngineer in the Southern AreaProduction Engineering Department(SAPED).

Prior to joining Saudi Aramco in2006, he worked as a summer traineewith the Ain Dar and Shedgum Unit of

the Reservoir Management Department for 8 weeks fromJuly through August 2004. Alaa has 3 years of experience,mainly in acid stimulation and well intervention.

He received his B.S. degree in Petroleum Engineeringfrom King Fahd University of Petroleum and Minerals(KFUPM), Dhahran, Saudi Arabia in 2006.

Walid K. Al-Guraini is a PetroleumEngineer working in the Southern AreaProduction Engineering Department(SAPED). He joined Saudi Aramco inFebruary 1997, working in theDevelopment Drilling Department.Walid has 13 years of experience,

mainly in drilling operations, production optimization andwell intervention.

He received his B.S. degree in 1996 in ChemicalEngineering from King Fahd University of Petroleum andMinerals (KFUPM), Dhahran, Saudi Arabia.

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