bluuebunny/crossref_metadata_2025 huggingface dataset:
Improving the Efficiency of Cold Rolling Process for Rotary Shouldered Connections
Authors: Imtiaz Khali , Mohammed Ismail , Gokhale Samit , Oak Sushil
Published: November 2015

Fatigue is the most common failure mechanism of rotary shouldered connections (RSC). To mitigate fatigue and to increase the fatigue life of the RSC, industry standards, including API 7-1 (API) [1] and DS-1 (DS1) [2], require cold rolling. During cold rolling, the thread root is deformed by rotating the RSC and applying radial pressure by means of profiled rollers. Usually this operation is completed on the lathe machine after cutting and final gauging of the connections.

The effectiveness of the cold rolling is influenced by the application parameters like roller dimensions, roller force, roller revolutions per minute (RPM) etc. Since these parameters are not specified in API, manufacturers use parameters specified in DS1 including the rotation speed of 1 RPM. This speed is difficult to achieve because most lathe machines do not have the provision to rotate at such low RPM. It also takes longer time making the process unproductive. As a compromise, some manufacturers manually rotate the samples resulting in increased time, inconsistent rotation and non-uniform application of compressive stresses.

To overcome the limitations discussed above, tests were conducted on numerous samples cold rolled at varying speeds. Extensive fatigue tests, residual stress measurements and metallographic evaluation studies were performed during this process. This paper presents the details and findings of this study. It concludes that higher rotation speeds not only provide consistent rotation but also improve the fatigue performance of RSC. The revised parameters as a result of this study are also proposed.
Relative Permeability Measurements to Quantify the Low Salinity Flooding Effect at Field Scale
Authors: Sorop Tibi G. , Masalmeh Shehadeh K. , Suijkerbuijk Bart M. , van der Linde Hilbert A. , Mahani Hassan , Brussee Niels J. , Marcelis Fons A. , Coorn Ab
Published: November 2015

In the last few years it has become widely accepted in the industry that Low Salinity Flooding (LSF) works by changing reservoir wettability towards a more water-wet state. Most of the published experimental data to quantify the LSF effect focus on comparing ultimate recovery of low salinity (LS) and high salinity (HS) waterflooding experiments either in secondary and/or tertiary mode. A wide range in incremental oil recovery is reported in the literature, from 0 to more than 20% of OIIP. To assess the potential of LSF and to enable upscaling of the LSF benefit to reservoir scale, the relative permeability curves for HS and LS brine should be determined. In only a few published cases, the experimental data was interpreted using numerical simulations to derive relative permeability curves for both low and high salinity water.

So far all of the LSF corefloods reported in the literature have been done using the unsteady state (USS) coreflooding method. Unsteady state corefloods are appropriate in evaluating the LSF potential qualitatively and to de-risk for potential formation damage due to clay swelling. However, USS corefloods can only measure the relative permeability curves after water breakthrough and they are sensitive to heterogeneities in the core samples. The steady state (SS) coreflood method, on the other hand, is less sensitive to sample heterogeneity and can measure the relative permeability curves over a wide saturation range.

In this paper we will present the experimental procedures and data measured during SS LSF core floods using less homogeneous core samples from a sandstone reservoir. Details of the experimental procedures to quantify the LSF effect were published earlier (Masalmeh et al. 2014). In this study a combination of USS and SS coreflooding experiments using in-situ saturation monitoring were performed, accompanied by spontaneous imbibition tests. Numerical simulation of the experimental data was used to extract the LS and HS relative permeability curves. While the Amott and USS experiments unequivocally showed a very clear positive LSF effect with no formation damage, SS corefloods tests were performed to better quantify the effect. The result of the tests, - to our knowledge - are the first to be reported in the industry for LSF on real rock material, allow extracting reliable relative permeabilities and enable upscaling of the LSF effect to field scale.
Facies, Deposition And Diagenesis Characteristics Of The Upper Kharaib Member (Late Barremian), Onshore Abu Dhabi, UAE
Authors: Wazir Zinhom El , Madani Noura Al , Omobude Osemoahu Abednego , Alhoot Abdul Rahman
Published: November 2015

The Upper Kharaib Member of the Lower Barremian in Abu Dhabi onshore is represented by the Formation-B, which is separated from the overlying Shuaiba formation by 45 to 50 feet of dense Limestone of the Hawar formation. It is classified into B-Upper and B-Lower, comprising seven reservoir quality sub-zones (BI, BII, BIIIU, BIIIL, BIV, BV and BVI) separated by six stylolitic intervals. The average thickness for B-Lower is about 100 ft as compared to 60 ft in the upper zone. This study provides integrated sedimentological and diagenetical characteristics - in a field-scale - of the Formation-B in Abu Dhabi, UAE.

A unified lithofacies scheme has been used to describe the Formation-B. These litho-facies have been grouped into eight genetically related lithofacies associations that reflect their corresponding deposition environments. The stacking of the lithofacies associations (inner ramp, mid-ramp and mid to outer ramp) define the broad 3rd order trends observed across the study field within the Formation-B, which have been compared to the regional sequence stratigraphic framework of Sharland et al. (2001).

The lateral lithological variations occur at a higher order (i.e. 4th/5th order), most likely driven by autocyclic topographic/hydrodynamic variations, in addition to sea level changes; these will impart lateral reservoir heterogeneity. Within subzones BIV to BI, variations in lithofacies associations are observed due to the patchy nature of the higher energy inner ramp facies.

The study concluded that the main controllers on reservoir quality distribution are texture and primary composition, as the matrix and grain ratio, together with allochems type, abundance, and size, define the genetically distinct characteristics of the lithofacies associations and provide the precursor fabric for subsequent diagenetic processes to occur. Cementation affects all the lithofacies; the morphology and pervasiveness of the crystals are dependent on primary and secondary pore space available for cementation. The key pore enhancing phases are dissolution events, mainly early and late dissolution enhancing micropores and enhancing/creating macropores, commonly partially or completely negating the effect of cementing phases. As the effects of the diagenetic overprint are linked to primary texture and composition, the distribution of the lithofacies and lithofacies associations will influence reservoir quality. The grainier lithofacies are more commonly seen to be influenced by pore-enhancing late dissolution phases, thus these facies host better reservoir quality. This is best developed in the upper portion of the Formation-B. The combined understanding of the sedimentological framework and the diagenetic overprint provides a robust tool for predicting the reservoir architecture.
Takreer's Integration with Other Operating Companies - Value Maximization Through Synergy
Authors: Al Hamed Omar
Published: November 2015

The objective of this paper is to showcase the strategic integration of TAKREER Ruwais Refinery within its existing Ruwais Refinery - East (RR-East), Ruwais Refinery Expansion - West (RR-West), upcoming CB&DC (Carbon Black & Delayed Coker project) facilities and also with other operating companies (OPCOs). The paper highlights how this integration enhances synergy amongst all OPCOs which leads to overall reduction in capital costs, GRM maximization, Energy Optimization and therefore leading to value maximization.

TAKREER'S project team judiciously conducted detailed technical and economic feasibility studies to ensure refinery configuration and its integration within TAKREER and with other OPCOs not only meet TAKREER's vision in becoming a World Class diversified Refining Complex but also realize the overall objective of ADNOC group of companies.

High Benzene Reformate streams from RR (East) and ADRD (TAKREER Abu Dhabi Refinery) are upgraded in RR(West)'s Bensat unit to produce Low Benzene Reformate. LPG from RR (East) & RR (West) is processed in RR (West) to maximize High octane Alkylate production replacing hazardous MTBE.

TAKREER'S CB&DC project would convert low valuable heavy bottom of the barrel feedstocks like Slurry oil from RR (West) & Vacuum Residue from RR (East) into high valuable specialized products i.e., Anode grade Coke, Carbon black, etc while ensuring Zero Fuel Oil generation from the Refinery.

Crude oil is sourced from ADCO and Natural Gas used as fuel is sourced from GASCO. Utilities i.e., Steam and water are produced as captive from within, power is sourced from TRANSCO. Nitrogen is sourced from ELIXIER. TAKREER's main product i.e. High valuable Polymer Grade Propylene product is exported to BOROUGE as feedstock to BOROUGE's Polypropylene units. TAKREER's upcoming state of the art Propane De-Hydrogenation Unit would not only utilize Propane & LPG streams from RR (West) & RR (East) but also use Propane stream from GASCO to produce Propylene. Similarly, Carbon Black product would be exported to BOROUGE. Liquid Sulphur product and LPG is sent to GASCO. To minimize loss of products or minimize downtime within TAKREER as well as across OPCOs, facilities are available for mutual sharing of streams like Hydrogen, Ethane Rich Gas and Butane streams can be shared within TAKREER'S RRE, RRD & CB&DC facilities.

Ethylene recovery and conversion of Ethylene & C4s into Propylene is an innovative and unconventional approach to increase Propylene production. TAKREER’ s upcoming PDH unit is the world's first facility in the world to be installed within Refinery complex. Similarly Carbon Black production from low value low-value Slurry oil is another novel idea towards strategic integration with other OPCOs.

Thus strategically integrated facilities contribute to overall reduction of capital costs and improves Operating margin thereby leading to increase in profitability.
Fracture Orientation and Fluid Saturation of a Cavernous-Fractured Reservoir Via Imaging of the Scattering Energy
Authors: Cheverda Vladimir , Lisitsa Vadim , Merzlikina Anastasia , Reshetova Galina , Shilikov Valery
Published: November 2015

We have developed justified, verified and implemented for supercomputers with parallel architecture the reliable instrument for the studying complicated processes of waves’ propagation in realistic 3D heterogeneous multiscale models of geological media - the special finite-difference method with local mesh refinement in time and space. On this base, it becomes possible to deal with realistic models and acquisitions and take into account both small-scale heterogeneities of a reservoir and mesoscale variations in overburden. This software was applied for simulation of seismic waves’ propagation through realistic synthetic models developed for some East Siberian oil field. We have found that orientation of fracture corridors and fluid saturation of reservoir microstructure has very specific impact in synthetic images of scattered waves, which can be used to develop predictive criteria in real life data processing and interpretation. These criteria are verified by comparison of predictions with well log data (fracture orientation) and permeability (fluid saturation) of a collector by test results.
The Role of Production Logging in Optimizing Unconventional Shale Gas Stimulation in Middle East
Authors: Bartko Kirk , Kurdi Mohammed , Zaouali Zouhir , Zeybek Murat
Published: November 2015

Most unconventional shale gas reservoirs are being produced through a series of hydraulically fractured stages distributed across horizontal wells. Different fracturing techniques are being used to maximize well performance in a most feasible manner. Some techniques may economically present more advantages than others.

The study outlines a workflow on how to select the right diagnostic tools, plan and design the logging intervention putting different well conditions in perspective such as variations in production rates, slugging, water recirculation, water loading and nitrogen (N2) lifting. The workflow also includes the critical steps needed during data acquisition and interpretation to provide a more accurate evaluation.

This paper illustrates two case studies. The first case discusses a horizontal shale gas well in the region that was completed with 12 fracturing stages. The second case was completed with 14 stages. Different fracturing techniques were utilized to maximize the production and the optimal hydraulic fracture design was investigated in terms of well productivity. The multi-spinner production log was combined with the pulsed neutron log (PNL) and water flow log (WFL) in one of the wells to determine the downhole flow profile along with accurate water entries due to different trajectories and low water rates.

Zonal gas and water flow production were obtained for each fracturing stage despite challenging well deviation and complex gas-water flow regimes. Pressure buildup data acquired simultaneously with the multi-spinner production log in an efficient manner led to more accurate reservoir pressure. Stages with water production were shut off successfully, reducing the water rate accordingly. These results were incorporated with the early fracturing data for a better understanding of the well performance and also to optimize the completion and fracturing design for future wells to be drilled in the same field.
CFRP Strengthening and Rehabilitation of Corroded Steel Pipelines Under Direct Indentation and Bending
Authors: Elchalakani M. , Almaskari F. , Alardhi M. , Alkhrdaji T. , Hill C.
Published: November 2015

Objectives/Scope

This paper develops a technique to rehabilitate damaged or sub-standard steel pipelines, which utilizes the lightweight, high strength and corrosion resistance characteristics of carbon fibres reinforced polymers (CFRP) composites have been proposed.

Methods, procedures, and process

The study conducted experimental tests for two series of CFRP strengthened and rehabilitated pipes under quasi-static large deformation 3-point bending. The main parameters examined in this paper were (a) the corrosion penetration in the wall thickness; (b) its extent along the pipe; and (c) the type and number of the CFRP sheets. The corrosion was artificially induced 360° around the circumference and in the wall thickness by machining, where four different severity of corrosion were examined of 20% (mild), 40% (moderate), 60% (sever), and 80% (very sever).

Results, observations, conclusions

The first series was for rehabilitation of 31 artificially degraded pipes with limited corrosion, which were repaired using externally wrapped sheets. The extent of corrosion along the pipe was in the range of Lc/Dn=1.0 to 8.0, where Lc=length of corrosion and Dn is the nominal diameter of the pipe. The second series represents rehabilitation of 12 degraded pipes with full corrosion along the length of the pipe. The extent of corrosion along the pipe in this series was Lc/Dn =8.0. The section slenderness examined in this paper was in the range of D0/t =20.32 to 93.6. The CFRP sheets were wrapped around the section in the longitudinal and transverse direction with a sufficient overlap. The results show that the combined flexural and bearing strength of the pipe can be significantly increased by adhesively bonding CFRP.

Novel / Additive information

This research and experiments developed an appropriate technique using CFRP, which significantly improved the repair and rehabilitation of corrosion in steel pipes. The percent increase in strength was mostly affected by the corrosion level where the maximum gain was 434% which was obtained for the most severe 80% corrosion in the wall thickness. The average increase in the load carrying capacity was 97% and 169% for the rehabilitation and strengthening series respectively.
Formation Pressure Evaluation for Producing Wells Without Shutting Down the Well, Using Multi Rate High Precision Temperature and Spectral Noise Logging (HPT-SNL)
Authors: Sarsekov Arlen , Al-Alyak Abbas , Al Neaimi Ahmed , Saif Omar Yousef , Helmy Mohamed , Akram Fazeel , Saber Mohamed , Bilbeisi Jawdat , Mansouri Tarik , Shnaib Fathi , Khamatdinov Rafael , Skutin Vasiliy , Farakhova Rushana , Aslanyan Irina , Makhiyanov Ruslan
Published: November 2015

Majority of the oil and gas fields in the UAE are mature multi-layered carbonates reservoirs, which determines complex vertical heterogeneity and challenging development of those reservoirs. Conventional methodology to measure sublayer pressure is to utilizing different wireline formation testers for any new well or worked over well before commissioning for production. Once well is completed and put on production; usually the average reservoir pressure is measured at the depth of perforation using conventional pressure build up (PBU) or bottomhole closed-in pressure (BHCIP) methods. Using conventional approach it is always difficult to understand which layers are more depleted than others, as only average reservoir pressure is recorded in the wellbore. In case of the heterogeneous multi-layer reservoirs, pressure measured conventionally in the wellbore will be at most of the times, inadequate for sublayer pressure estimation.

This paper will describe new methodology of formation pressure evaluation, as well as real case study done in one of the developed offshore carbonate field in the UAE. This method allows measuring each sublayer pressure for producing wells without interruption of the production and properly defining any differential pressure between sublayers. This will help when applying any gas shut-off or water shut-off techniques and prolong the life of producing wells, as well as to help future development of the field. The determined reservoir pressure for each layer has been compared with recent formation pressure tester measurements obtained for this well. The pressure measurement is in the range of 20 psi tolerance.

Identification of sublayer reservoir pressure for each producing interval is vital for highly heterogeneous multi-layered reservoirs. This technique is important for gas and water production management when one or several sublayers become depleted. Appropriate action for gas/water shut-off technique can be applied in the right time which will help to manage reservoir efficiently, as well as reducing the cost for conventional pressure measurements and eliminating the loss of production due to shut in time for pressure stabilization during conventional BHCIP or PBU.
Wettability Alteration in Hydraulically Fractured Tight Sand for Flow-back Improvement
Authors: Mohamed Fathima , Al Hinai Mohammed , Al Nabhani Hamood , Yu Sung , Sarkar Sume , Haghighi Manouchehr
Published: November 2015

After hydraulic fracturing, the flow-back of fracturing fluid is necessary before the gas production starts. A review of fracture treatments indicates that the incomplete return of treating fluids is a reason for poor gas production. It is believed that the water blockage in tight sand limits flow-back in low permeable gas wells. In this paper, it is proposed to reduce water blockage effects by wettability alteration in a fracture plane surface by introducing a novel set of materials that alter the wettability of the sand from a largely water-wet state to a less water-wet state. Consequently, this decreases the water imbibition from fracture face into the matrix and also reduces the capillary holdup. Four different easy to obtain, non-hazardous materials namely, talc, polytetrafluoroethylene (PTFE), activated carbon and silica nanopowder were evaluated for their efficiency to alter the wettability using contact angle measurements and spontaneous imbibition tests. The results of such study indicate that the PTFE was the best material by improving the wettability by more than 90 degrees and decreasing the water imbibition rate by 7 times. However, if a non-polymer solution is required, talc is a good alternative with moderate results. It is a readily available mineral and non-toxic. To determine how these results translate in terms of incremental recovery of the flow-back and the gas production, a coupled fracture propagation model with multiphase reservoir simulation has also been performed. The results predict an overall increase of gas production and a better water flow-back.
Learning Styles and Learning Strategies of Geology Technology and Exploration Information Technology Students in Petroleum and Natural Gas Higher Institute of Technology and Training in Dammam, Kingdom of Saudi Arabia
Authors: Anicas Roel Palo
Published: November 2015

The study is aimed to determine the relationship between the learning styles and strategies of 321 students in Petroleum and Natural Gas Higher Institute of Technology and Training in Dammam, Kingdom of Saudi Arabia. It sought to assess the extent of practice of the students' learning styles along Visual, Auditory and Tactile learning styles. Further, the level of students' preference in the following learning strategies: Memorization, Problem Solving, Experimentation, Group Study and Immersion was assessed by institute and year levels and to determine if there exists a relationship between the extent of practice of the above mentioned learning styles and the level of preferences of the learning strategies.

The investigation made used the descriptive method. The stratified sampling is utilized the sample size of the study. Data gathered were tabulated and interpreted using statistical tools such as weighted mean to assess the various learning styles and on the level of students' preference on the different learning strategies, correlation analysis for the significant relationship and analysis of variance (ANOVA) for the identifying the significant differences in learning styles and learning strategies according to levels.

It is revealed that the results showed a homogeneous type of students in spite of differences in institutes where they belong. For each of the learning styles, students practice much of them. Learning styles are not determined by inherited characteristics, but develop through experience. By comparing the computed weighted means, it could be observed that Tactile is consistently in number one slot having weighted means of 3.85 for Level 1, 3.80 for Level 2 and 3.78 for Level 3 while Visual followed at weighted means of 3.70, 3.65, and 3.59 as rated by Level 1, Level 2 and Level 3, respectively. Auditory learning style is also much practiced by the students in the three levels where Level 1 students rated this style a weighted mean of 3.66, Level 2 students rated this style also with a weighted mean of 3.64 and for Level 3, a weighted mean of 3.48. Level 1 to Level 3 highly preferred experimentation, problem solving, immersion and group study are highly preferred while the memorization is moderately preferred. This corroborated with the conclusion that students in order to have a better grasp on the topics or lesson, involving other senses not just the eyes (normally utilized in memorization).

A proposed developmental plan embedded with importance of context to further enhance and develop the students learning styles and learning strategies will be given ample importance which encourages the students/learners to understand the technical communication of teaching-learning process as a necessarily tool for development and to become a globally competitive Saudi Nationals.
Leadership Styles and Management Competence of Administrators of Petroleum and Natural Gas Higher Institute of Technology and Training, Dammam, Kingdom of Saudi Arabia
Authors: Anicas Roel Palo , Alwehaimed Bassam
Published: November 2015

This study determined the leadership styles and management competence of top and middle administrators as a basis for a proposed training plan for the top and middle administrators of the of Petroleum and Natural Gas Higher Institute of Technology and Training in Dammam, Kingdom of Saudi Arabia.

This study utilized the descriptive-correlational design to determine the relationship between leadership styles and management competence of school. This study employed quantitative and qualitative approaches. The quantitative analysis was used for the profile, leadership styles and management competence of administrators while the strengths and weaknesses for qualitative was proposed based on the findings of the study. Fifteen (15) school administrators determined their own leadership styles. Their subordinates were rating them based on the management competence criteria, indicators and parameters of the 15 administrators, there was one (3) school administrator, 7 program heads, 3 subject coordinators and 2 non-teaching heads.

On the level of leadership styles of school administrators. The institute is run by the administrators with collaborative leadership styles rather than empowering and autocratic. The finding discloses that the administrators often ask and include their employees in the decision making process. Most of the activities conducted are being participated by their employees as part of the organization objectives. The school administrators as key players create an environment where the employees are part in the realization of the vision, mission and goals of the institute. Employees are given chance to fulfill their objective, utilize their knowledge, creativity and ingenuity to solve organizational problems. Likewise on the level of management competence of school administrators and they obtained high level. The significance of the relationship between leadership styles and management competence of administrators and they revealed no significant relationship. This implies that the leadership styles of administrators has nothing to do with their management competence. This implies further that the management competence of the administrators is not related to their leadership styles. It is concluded that the administrators are collaborative leaders. They are excellent in resource management, teaching and learning, creating a conducive learning environment, community building, school planning and improvement and leadership.

The proposed training plan will be a tangible and good source for the development of the administrators and their exposure to training is associated with their management competence. Participation of trainings would contribute to improved management competence of the institutes administrators.
Advancements in Gas Condensate Reservoir Surveillance: Well Testing to Production Forecasting
Authors: Karacali Ozgur , Hernandez Erika R. , Al-Ghaithi Ali
Published: November 2015

Well testing is an integral part of successful exploration and production programs. Conventional techniques to acquire reservoir surveillance data and develop oil fields are not rigorously applicable for complex gas condensate reservoirs. Once gas condensate reservoirs are put on production, reservoir models need to be history matched as early as possible. Moreover, reservoir model should periodically be updated with gradually unfolding production data. Reservoir models will not be representative for future production forecasting unless accurately measured dynamic flow rate and pressure data are integrated into geologically consistent static reservoir models. In this paper, production testing via mobile flowmeters of gas condensate fields in central onshore Oman, is presented.

In these fields, an extensive number of well tests (more than 1,000) have been performed through mobile well testing units for more than a decade. Condensate to gas ratios (CGR) do vary significantly because most of the wells are producing commingled from two to three clastic reservoirs that are continuously being depleted. Acquiring accurate liquid and gas flow rate measurements was a challenge because average producing gas volume fractions (GVF) were greater than 98%. Under these conditions, felicitous fluid characterization is paramount for unerring gas and liquid flow rate measurements. Therefore, Petroleum Development Oman (PDO) has decided to characterize the fluid properties by capturing surface fluid samples while testing the wells at various operating pressures and temperatures. Most of the wells also had production logging tool (PLT) measurements performed to allocate surface productions to various reservoir units.

In summary, multiphase well testing coupled with fluid sampling and analysis significantly helped to build an accurate production history that is used for updating reservoir models. Well testing and fluid analysis greatly assisted well and reservoir management efforts. Oil and gas compositions are analyzed for numerous flowing conditions. Heptanes plus (C7+) mole percentages of the reservoir fluids are used to establish CGR correlations in addition to various pressure/volume/temperature (PVT) and flow rate relations.

Frequent well testing and surface fluid sampling indicated that the producing reservoir layers are depleting at different rates after more than a decade of production. CGR trends illustrated that certain wells produce more gas, leaving behind dropped-off condensate in the reservoir. This result supported the informed decision-making process to maximize gas and condensate production from specific areas in the field. In addition, well testing results helped PDO to rank the wells and analyze the production decline. In this paper, advancements in gas well testing methodologies successfully adapted for gas condensate reservoirs, will be presented in detail in conjunction with lessons learned and good practices.
Qusahwira from Project to Production: Establishment of Business Processes Model
Authors: Mohamed Al Jaberi Adel Saleh , Al Ahmed Easa Ismael , Al Zaabi Abdulla Rashed , Rabii Walid Mustafa , Bani Hashim Ahmed Mohamed , Martto Joshva
Published: November 2015

South East (SE) is one of the major assets in Abu Dhabi Company for Onshore Petroleum Operations Ltd (ADCO)'s portfolio. Until 2013, SE was producing from fields (Asab, Sahil and Shah) and 2 new fields (Qusahwira & Mender) which were under development. The initial operation philosophy for the new fields was to have a centralized operation organization with necessary support functions at Asab and to deploy only the facility operating resources at respective fields.

Due to the change in company strategy, SQM (Shah, Qusahwira & Mender) has been spin-off from SE and a new organization was put in place while Qusahwira (QW) was moving from commissioning to production in 2013.

SQM Operation Management Team (OMT) has initiated a business transformation program to ensure required business processes were in place for the new organization to seamlessly integrate the development asset in to a producing portfolio. Assigned task force acted as a program management office and process champions were allocated within the major Level 1 (L1) processes for its implementation. Finally SQM has successfully integrated into the existing organization through implementation of necessary business process within the asset.

The paper will discuss the detailed methodology, challenges faced and the change management initiatives implemented during commissioning to production transition.
A Development Framework Plan for the Emarati Workforce in ADCO
Authors: Al Sayegh Ali Ahmed
Published: November 2015

The paper discusses the importance of a development framework for the Emarati workforce. To do so the Competency Assurance Management System (CAMS) program will be presented along with how it has helped integrate the Emarati workforce into ADCO's culture. Additionally, the Career Ladder and Succession Planning processes will also be presented to shed light on how they have helped in creating a foresight in terms of career development for the national workforce.

The first section of the paper will focus on the challenging nature of Emiritization. It will answer the question of what challenges the mandate of Emiritization brought to companies it was imposed on and how they adopted to challenge.

The following section of the paper will then focus on the Competency Assurance Management System. The section is divided into three different subsections, the first subsection will focus on the structures of the CAMS, the second subsection will focus on the overall challenges the CAMS faced and finally the last subsection will focus on the value CAMS brings to ADCO.

The third section of the paper then illustrates the continuous development of Emaratis within ADCO even after they have completed the CAMS. The section is divided into two subsections one that focuses on the Career Ladder profiles meanwhile the other focuses on the Succession Planning profiles.

Flowingly, section four discusses what can be observed from the previous sections and illustrates how the Emarati workforce has changed its perspectives. Finally then the paper is concluded with a discussion on the set of challenges that ADCO might face in the future and the different methods it might adopt in order to face those challenges.
A Novel Enhanced Oil Recovery Technique: Experimental Results and Modelling Workflow of the DME Enhanced Waterflood Technology
Authors: Chernetsky A. , Masalmeh S. , Eikmans D. , Boerrigter P. M. , Fadili A. , Parsons C. A. , Parker A. , Boersma D. M. , Cui J. , Dindoruk B. , te Riele P. M. , Alkindi A. , Azri N.
Published: November 2015

Dimethyl Ether Enhanced Waterflood (DEW) is a novel and promising solvent-based EOR technology developed by Shell. Dimethyl Ether (DME) is a widely-used industrial chemical which is applied as a water soluble solvent for EOR applications to enhance a conventional waterflood. Once the DME-brine solution is injected into the reservoir and comes in contact with the oil, the DME molecules partition into the oil phase which leads to oil swelling and mobilization of residual oil. Moreover the partitioning of the DME into the oil phase decreases the oil viscosity and improves its mobility. The combination of these effects results in both a significantly higher ultimate oil recovery compared to the conventional waterflood as well as accelerated oil production at lower energy footprint compared to thermal technologies. As the solvent is water soluble, it can be very effectively back-recovered from the reservoir by re-dissolving the trapped DME in the DME-free chase water slug. The solvent is recovered from the produced oil and water streams at surface and re-used. The main objectives of this paper are to present the first experimental results, explain the physical mechanisms of this novel concept and demonstrate the extra oil recovery. Additionally, modeling workflows used to interpret the experiments and predict the benefits of field EOR application are illustrated.

To gain an insight into physical mechanisms behind the DEW, develop modeling workflows and de-risk the technology, an extensive experimental program was set up to investigate both the fluid-fluid and rock-fluid interactions. Phase behavior of DME/brine and DME/crude mixtures has been carried out, with a focus on the partitioning of the solvent between brine and crude. Mixing rules for properties affecting the phase mobilities have been determined. In parallel, a number of coreflood experiments were conducted on both carbonate and clastic cores of varying permeability to investigate the dynamic DME/crude behavior and DME/rock interaction. PVT experiments were used to build phase equilibrium models. Based on these PVT models, the coreflood experimental data was matched and interpreted using numerical simulation.

Coreflood experiments confirmed the phase behavior-driven character of the DEW technology. A good match between the experimental and simulated oil recovery was obtained in most cases. This shows that PVT models, generated using measured basic data, are in a good agreement with the dynamic coreflood experiments.
Monitoring & Surveillance Improve ESP Operation and Reduce Workover Frequency
Authors: El Gindy M. , Abdelmotaal H. , Botros K. , Ginawi I. , Sayed E. , Edris T.
Published: November 2015

The Western Desert in Egypt has multiple fields in which most wells are artificially lifted. Wells with ESPs represent the major percentage of oil production by volume in that area. ESP run life is a principal criteria that is typically evaluated before the initial design and throughout the well's life time. Most wells are remotely positioned from one another and from the main gathering stations (2 to 8 Km. approximately). This is one of the major challenges when trying to maximize uptime and reduce the production deferment.

Operational issues including power supply and capacity limitations as well as changing inflow conditions can have negative impact on the ESP run-life, predominantly caused by excessive trips and shutdowns. Also such trips will result in lengthy downtimes due to the remoteness of the wells. On the production side, these trips will ultimately have a major effect on production targets due to intermittent deferment.

ESP wells connected to real-time monitoring and surveillance systems incur less lifting costs because of proactive responses and early detection of incidents. Systematic alarms along with pro-active remedial actions can minimize such preventable trips while maintaining the integrity of the ESP, eventually extending its run life.

This paper discusses a number of case studies showing how the implementation of such system prevented trips in some situations and allowed making key decisions and recommending remedial actions to optimize the ESP operation.
Autonomous Inflow Control Device - A Case Study of First Successful Field Trial in GCC for Water Conformance
Authors: Iqbal F. , Iskandar R. , Radwan E. , Abbas H. Abdel-Moneam , Douik H. , Least B. , Mohamed Z.
Published: November 2015

The paper presents the case study of first successful Autonomous Inflow control Device (AICD) application in the GCC region. The AICD works on the principle of viscosity difference of the produced fluids and resists the unwanted fluid (water) to maximize the oil flow rates. The innovative design overcomes the subsurface uncertainty and changes due to dynamic reservoir behavior (changes in Sw, water break through, fracture etc.) by facilitating oil flow through a short and direct path of least resistance, thereby reducing watercut and increasing oil production rates relatively.

The paper elaborates the design considerations and implementation methodology for AICD completion installed in a watered out well of naturally fractured reservoir. A rapid increase in watercut was observed soon after commissioning the well on ESP which resulted in rapid decline in oil production rates. An integrated subsurface approach was adopted to analyse the problem, evaluate probable causes and identify potential remedial for the subject oil well. The subsurface and production data including seismic, borehole image, open hole and production logs, etc. were incorporated through a pragmatic approach in the design process. The conventional Inflow Control Device (ICD) was also compared to establish the added value.

In the end, the results of the successful AICD deployment are presented which indicate 400% increase in oil production with significant drop in watercut. The well is currently on production has produced 3 times more cumulative as compared to the pre-workover cumulative in 2.5 years. Overall, the AICD deployment resulted in overcoming the reservoir heterogeneity and improved sweep efficiency with a significant gain ultimate recovery from the well.
Risk Based Inspection Planning Using Bayesian Updating
Authors: Atia Mohamed , Manzocchi Mark , Munday James , Azouz Amr , Omar Tarek , El-Khouly Wael , AbdelKhalek Ahmed
Published: November 2015

Offshore Structures are typically designed with a target end of field life between 20 and 30 years. Many offshore Structures remain in service while exceeding their designed life which requires robust methods for evaluating and maintaining target risk levels through regular sub-sea inspections.

Risk based inspection plans are generated based on strength and fatigue analysis (typically S-N based fatigue assessment) which involves a number of uncertainties which are inherent to the fatigue process. These uncertainties inevitably lead to inconsistencies between analysis predictions and the outcome of underwater inspections. Although the inspection findings are acknowledged, there is generally not much effort made to make use of the inspection findings to optimise future inspection plans.

This paper applies reliability updating methods to optimise inspection plans (inspection intervals) using fatigue reliability based on the results of in-service inspections. This methodology forms part of the work requested by ADMA-OPCO during the customisation of Atkins Fleet Management System (FMS) for the application to their Offshore Structures fleets. It has been reviewed and adopted by ADMA-OPCO to replace existing qualitative methods. The methodology works towards optimising their inspection efforts and cost to maintain acceptable target risk levels.

The methodology is based on evaluation of the SN fatigue reliability since the SN Curves are implemented in the fatigue design methods outlined in International Standards. A probabilistic model for fracture-based reliability calculation is developed by calibration of initial crack size to match SN based fatigue reliability. This model enables utilisation of the Bayesian updating techniques which allow incorporation of the inspection results in the calculations.

Environmental data from Umm Shaif Field (ADMA-OPCO) have been utilised in the calculations along with fatigue design SN Curves from the API RP 2A international standard. The calculations target the acceptance probability of failure levels of a critical component (hotspot) with a target design life of 30 years.

In the event that no fatigue cracks are identified through in-service underwater inspections, the existing inspection plans can be revised utilising the developed methodology to optimise the inspection intervals, leading to cost saving and optimisation of the inspection plan. Major in-service inspection campaigns have been executed by ADMA-OPCO where no fatigue cracks were identified. Other operators within the region have also concurred that no fatigue cracks were observed during in-service inspection campaigns, which indicate that the methodology proves effective in optimising inspection costs within the region.
Suppliers Compliance Assurance Mechanism
Authors: Alashqar Ameed , Yoo Jaeho , Elshareef Abdulla , Awda Hisham
Published: November 2015

Over 60% of the "Mega-Projects in Oil production and development" budgets is allocated for equipment procurement, therefore, most of the EPC contractors in today's competitive bidding and the lump Sum Project environment in the UAE put most of their effort to save in this area to maximize their profit.

The equipment supply sustainability risk levels elevated in the last decade due to collapsed of several major suppliers, the scatter of supplier experience, large acquisitions of specialized manufacturing sourcing from low cost centers and the trade between cost and quality.

A Suppliers Compliance Assurance (SCA) Mechanism has been developed to address such market challenges to fill the gaps between end users and vendors for maintaining the specified quality of end products.

With this Supplier Compliance Assurance Mechanism, ADMA-OPCO was able to set specific requirements and goals and enabled getting involved at critical stages on the right time to ensure the agreed scope is decided and with sufficient time to secure corrective measures and Contractor's supplier compliance in a transparent environment.

This in turn will contribute to develop company's organizational process assets for future challenges, to encourage young engineers to broaden their capabilities and to drive us towards e higher fficiency and excellence.
Production Management System to Enhance Collaboration and Production Surveillance, Garraf Oil Field
Authors: Didanloo Ali , Rivadeneira Ivan Marcelo , Idris Khairul Nizam , Latef M Zukhairi
Published: November 2015

Production engineers frequently use back allocation to estimate actual production volumes from wells based on frequent well test data or theoretical calculations using well and reservoir characteristics.

PETRONAS executed a centralized production data management system from early days of production to establish a scalable and reliable workprocess among the organization. The production and operation data management system of the field supports data collection, QC, validation and production back allocation as well as production downtime optimization.

The new system provides a means to visualize complex networks, verify the production streams, track gathering systems functionality through time and derive the allocation networks.

The various downtime coding and quantifications, helped Petronas to quantify the root cause of production shortfalls and optimized the unwanted shut downs.

The new system has improved the data quality and reliability and has made the data transparently available to the various stakeholders in the organization.

After the new back allocation system became fully operational, Petronas started to realize the following benefits from this successful implementation. Determine the production quantities of each well and reservoir for production accounting.Quality check and approval for the test data before being used for further calculationsAbility to allocate production, where accurate measurements are not possible or cost effective.Ability to determine fluid flow quantities through every strategic point in the network

The current paper describes the challenges and benefits of the subjected system implementation.