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CONTACT INFORMATION:
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Personal Details:

* Gender: Male.
* Date of Birth: 1969.
* Nationality: Syrian.
* Family: Married to a Syrian nationality (Bachelor degree) with 1 child (3 years old).

Education:

* B.Sc Physics, 1999 University of Damascus.

Summary of Qualifications & Performance:

* Operational experience in Open Hole Logging measurements in both Clastic and Carbonate reservoirs, on both wells drilled using water based mud system and synthetic oil based mud: Logging Programs, Data Analysis and maintenance, Quick Look Interpretation and final Formation Evaluation, integrating and presenting results.
* Follow up MWD data for Well A: integrate results with the team for geosteering and making decision.
* Acquire WL formation pressures, analyze results, and integrate it with the team to give advice to managers for production/injection and perforation strategy.
* Familiar with CMR and T2 analysis: Logging program and interpretation.
* Familiar with image log interpretation and integration with geologist (UBI/OBMI).
* Evaluate Cased Hole logs for reservoir surveillance and Hydrocarbon tracking, or to assess inflow (and injection) performance, (performed numerous TDT log interpretations and Production log data analysis in different reservoirs and well completion environments).
* Successfully completed a field study for the field ABC (14 producer and 4 injector wells) within an integrated field study team. As a result of the study, there were recommendations to drill 5 new wells in the field, one well to be abandoned, perforations and water shut off's to enhance oil production and reduce water cut and TDT/PLT jobs to be performed for more information.
* Establishing parameters for Open Hole and TDT log interpretation.
* Experience in the use of rock typing and its integration into petrophysical interpretation.
* Edited density and sonic logs in ABC wells for seismic purposes (e.g. inversion).
* Exposure to Petroleum Engineering activities from field development planning to well planning and operations.
* Part of different multicultural and multidisciplinary integrated operations and field study teams.
* One of 4 Petrophysicists who independently participate in petrophysical duty scheme.
* Familiar with all facets of open and cased hole logging using Schlumberger tools.
* Teaching basic Petrophysics and physical principles of logging tools to junior petrophysicists.
* Supervising petrophysical data management (QC received data, rush print and digital, and keep eye on archiving data).

Professional Experience:

2006-Present Petrophysics Section Leader
AFPC / Petrophysics department

* Responsible of managing, integrating, presenting and reporting all Open and Cased Hole Petrophysical activities for 14 fields with over 400 wells with different types of reservoirs and depositional environments, and give advices for decision making.
* Supervising and coaching a junior Petrophysicist.

2005-2006 Field Study Petrophysicist.
AFPC / Technical Study Center

Performed Petrophysical Studies integrated with a field study team:

* Data quality check and Depth matching.
* Established petrophysical parameters for Open Hole formation evaluation.
* Concluding fluid density by correlating core to WL data.
* Porosity-Permeability relationship and X-plot facies analysis.
* RFT analysis to determine field FWL.
* Saturation Height Function.
* Editing logs for seismic inversion.
* Production Log analysis.
* Established parameters for TDT interpretation.
* Petrophysical Uncertainties.

"For more details, please look at the attachment below".

2001-2005 Operations Petrophysicist
AFPC / Petrophysics department

* ntegrated Petrophysicist in a high activity environment. (35 new successful wells and 80 TDT/PLTs per year).
* Petrophysical Responsibility for six fields with 120 wells, where open and cased hole logs are evaluated day-to-day including Triple Combo, PEx, RFT's, TDT's, and PLT's.
* Member of six multidisciplinary teams charged with proposing wells and making recommendations for development.
* Planning and logging programs for WL and MWD jobs of new wells.
* Active participation in well reviews and yearly field development planning cycle.
* Established Petrophysical Evaluation Parameters.
* Provided reservoir properties as input data for reservoir monitoring.
* Keep the petrophysical logs database up-to-date.

Language Proficiency:

* English: Very Good
* Arabic: Native Speaker

IT Experience:

* Fully conversant with SHELL software LOGIC in UNIX environment.
* Skilled user of UNIX Operating System.
* Fully conversant with PC software (Win 2000, MS Office, Xvision).
* Able to quickly learn new software.
Training:

2007 Carbonate Reservoirs 1 week ResModTec UAE
2006 NMR Logging Workshop 1 week SPWLA China
2006 Applied Structure Geology 1 week ResModTec Syria
2006 Carbonate Petrophysics 1 week Petroskills-OGCI UAE
2005 Sandstone Reservoirs 1 week NEXT-SLB Syria
2005 Production Geology for Other Disciplines 1 week Petroskills-OGCI UK
2004 Petrophysics-P262 2 weeks Shell Holland
2003 Applied Well Log Interpretation 2 weeks Tri-Star Egypt
2003 Wire Line Logging 1 week SLB Egypt
2002 Routine and SCAL Core Analysis 2 week Tri-Star Syria
2001 Basic Logging and Petrophysics 3 days Shell & SLB Syria
2001 Basic Petroleum Engineering 11 weeks Tri-Star Syria

References:

* Robert Pimentel, Head of Petrophysics, AFPC, TSC, Damascus, Syria.
Email: r.pimentel@afpc.net.sy, tel (off): +963 11 618 0459, mob +963 933 619 639.

* Frans Hermsen, Senior Operations Petrophysicist, South Rub Al-Khali Company Limited, KSA. Email: frans.hermsen@srak.com.sa, tel: +966 3895 8851, mob: +966 50 369 5640.

Attachment:
, Summary of the performed field study,

1.Field Study Justification:

There are 2 main reservoirs in the ABC Field, Current Recovery Factors for the Reservoirs B and A are 30% and 10%, respectively, which are lower than those of surrounding fields. A number of uncertainties have been identified associated with such low recovery factors:

* Reservoir A continuity and connectivity.
* Reservoir A and B interaction.
* Sweep efficiency by water-flooding.
* Poor productivity in Reservoir A.

The proposed study aims to provide reasons to the above questions and advise on an optimal sub-surface development plan for the field.

2.Objectives of the study:

Phase 1:

* Examine the potential for further development from the Reservoir A.
* Understand the Reservoir B behaviour in particularly the efficiency of the water-flood mechanism, and develop an optimization plan.
* Provide a technical feasibility study to justify drilling the currently planned well in the Reservoir A.
* Provide opportunities for the optimum development plan for 2007.

Phase 2:

* Carry out a seismic inversion study to assist in defining the reservoir property distribution
* Generate a 3D static model incorporating the inversion results
* Update the hydrocarbon in–place volume distribution
* Generate dynamic models for the purpose of reservoir production optimisation of the reservoir B and sub-surface development planning of the reservoir A.
* Create a ranked and risked portfolio of sub-surface development opportunities.
* Generate a reservoir management and surveillance plan for the field.

3.Work Plan:

A phased, toll-gated approach is to be undertaken for the integrated study, including the following steps:

Phase 1:

1.Review previous studies / work
2.Integrated well and reservoir behaviour review
3.New structural seismic interpretation and coarse 3D static model
4.Productivity analysis – Reservoir A
5.Complete discipline data integration

Phase 2: Detailed Static and Dynamic modeling.

4.Petrophysicist Tasks:

Phase 1:

* Create sums and averages per well and per reservoir unit.
* Review Petrophysical (PP) evaluation parameters for both open and cased hole, based on CCA and SCAL Core data.
* Establish net reservoir criteria for static and dynamic models [jointly with Geologist(GG), Reservoir Engineer(RE) and Production Technologist(PT)].
* Evaluate wells and determine net reservoir, porosity and saturation.
* Evaluate wells and determine cased hole evaluation (TDT/PLTs).
* Interpret RFT data and log data and establish FWL/OOWC; estimate COWC from TDT
* Create porosity-permeability relationships.
* Establish saturation-height functions (together with RE), based on both log and cap curve data.
* Define main petrophysical uncertainties.
* Integration with other disciplines.

Phase 2:

* Generation of multiple-realization models for porosity, net-to-gross and permeability.
* In-place volumetric estimates based on well data realizations.

4.Work performed by the Petrophysicist:

1.Checked and reviewed the reports of previous studies and reviews.

2.Checked the availability of the data: Open and Cased Hole logs, RFTs, Cores taken and core reports.

3.Checked the quality of the OH logs and performed depth shifting or editing where required.

4.Provided the GG with the edited and shifted Rho-data for correlation and formation tops.

5.Determined parameters for OH formation evaluation:

i.Porosity parameters: we mostly calculate porosity from density:

* Defining Rhoma: Made histograms of the measured grain density from the CCA reports and took the average as Rhomatrix parameter.

* Defining Rhofl: Made X-plot of in-situ core porosity vs. log density, using the Rhoma value @ Phi=0 to make a regression line, my Rhofl will be the reading of density @ Phi=1, this was done 4 times to cover the 4 cases of OBM over oil/water bearing zone, and WBM over oil/water bearing zone.

ii.Archie parameters: (m, n and Rw)

* Defining m: in order to take the average of m reading in the SCAL reports, I X-plotted all the measurements of m vs. FRF and concluded the slope of the regression.

* Defining n: The technique of porous plate was used to measure n which is not recommended. It gave unreliable measurements, so the standard n=2 was used.

* Defining Rw: Picket plot technique was used to determine Rw. The result was confirmed by using Schlumberger chart after acquiring results of a salinity analysis sample.

6.Acquired formation tops from the GG and loaded them into the software for OH evaluation.

7.Analyzed RFT pressure data and determined gradients in each zone of each well.

8.Run the OH evaluation, and shared results with the team, and provided the GG with the evaluation output as summary tables (including net thickness of the reservoir, gross, n/g, porosity, and saturation): per well, per units and subunits.

9.integrated RFT pressure and logs analysis with the reservoir engineer(RE) and GG to determine FWL of the field.

10.Porosity Permeability relationship (integrated with the GG):

* There are 2 main reservoir in the field: one of them was clearly divided into 2 separated facies on the X-plot with 2 classes of porosity supported by the core description with few scattering points.
* The other one was more complicated, the facies based on the core description were mixed, plotted the data by well, and by integrating with the GG it was noticed that the wells in the north-east of the field (where n/g is higher) are better quality than in the north-west (this formation was eroded in the south). As a result, was agreed to divide it into 3 facies.

11.Built from logs a saturation height function model and provided the concluded formula and transition zone to the reservoir modelers.

12.TDT/PLT analysis:

* Determined parameters for tdt interpretation: Ósh, Ów, Óhc, Óma.
* Discussed the injection and flushing scenario with the RE before running the tdt evaluation
* Analyzed the production log and compare it with the results from the tdt.
* QA/QC the results together with the RE.

13.Defined petrophysical uncertainties for the PP outputs: Porosity, N/G and HC Saturation and shared them with the team.

14.Edited density and sonic log (by integration with the Seismologist) in support of the seismic inversion study.

15.An extra task for PP was to evaluate porosity in the carbonate reservoir C (a formation with mixture lithology deposited directly above the reservoir B), and generate porosity-permeability relationship and provide results to the reservoir modelers:

* Performed lithology analysis using density-neutron and sonic-neutron SLB charts.
* Performed porosity evaluation regarding the washouts and lithology in each well (limestone, dolomite or sandy limestone).
* Used the standard parameters(m=2, n=2) for formation evaluation due to the absence of core measurements.
* Used the core measurements of few meters in one of the wells to generate Phi-K relationship.

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