bluuebunny/crossref_metadata_2025_split huggingface dataset:
Marine Training Program for UAE Nationals
Authors: El Shehawy Mahmoud , Younes Helmy 
Published: November 2017

Abstract
Working on board Mobile Offshore Drilling units of National Drilling Company, require workforce with talented, high skills, knowledge and training to ensure that everyday operations can be undertaken safely and professionally. Having crews with the right competence, integrating education, training experience can perform the tasks accurately. The training program that the worker will receive must be of such quality and standard that personnel can be reliable to fulfill their task completely and securely.
NDC have a vision to promote Young local UAE for the technical positions on the drilling units, one very important post is the post of barge engineer, since there is no national academy to graduate Marine engineers, NDC doesn't have any UAE national barge engineer.
Consequently, NDC took the initiative to start a new program for training young UAE nationals both theoretically and practically in order to be qualified as Assistant Barge Engineers. Theoretical training has been done in collaboration with internationally recognized organizations like Maersk training (Denmark) and DNV-GL (Norway & Germany). On the other hand, on job training was carried out onboard NDC drilling jackups under the supervision of the experienced rig barge engineers. Allowing the young candidate to see and work with their own hands to feel the actual job he is going to occupy in the future.
In addition, another program has been created as a continuity of the first program to promote those candidates to be fully integrated as Barge engineers. One of the most important parts of this training was simulator training in Denmark to put the candidates into simulated real time scenarios where fast decisions needs to be taken.
Thinking Global, Acting Local: Customising Talent Development with International Exposure
Authors: Sequeira Neville , Gandhi Anoop , Almoosa Zakeyya 
Published: November 2017

Abstract

Objectives/Scope
A career path is comprised of a sequence of jobs, ideally with increasing complexity and responsibilities that help to make up a career plan. A career path typically includes the jobs that allow an individual to progress towards his or her targeted goals and objectives.

Methods, Procedures, Process
Total Abu Al Bukhoosh is part of the Total Group, a global energy company with operations in over 160 countries and a wealth of experience, procedures and processes covering all areas of Oil & Gas operations. Its culture of innovation is evident in its support functions as well and can be seen in various people development initiatives. We in Total Abu Al Bukhoosh, have leveraged this expertise to adapt some of the established career paths available with our Head Quarters for local conditions in Abu Dhabi. Applying these modified career path processes to our young Emirati Engineers in challenging areas like Process, Drilling and Reservoir Engineering has borne rich dividends and produced some impressive success stories.

Results, Observations, Conclusions
These "localized" career paths incorporate jobs in multiple geographic locations and in all cases involves an expatriation abroad. For example the path for a Process Engineer involves 2 years onshore followed by 2 years offshore and subsequently 2 years international expatriation in a full time operational position in the Group.
This not only benefits Total Abu Al Bukhoosh, but also allows the Group to take advantage to exchange some of their young talents to work on our sites. Some of our best talents go on to find international careers within the Group. Once the impatriate returns from his expatriation, he is able to diversify into other expertise streams, not necessarily limited to his domain. For example a Process Engineer can diversify in to other operational streams such as Wells Performance, Drilling, Safety, Projects, etc.

Novel/Additive Information
To date this strategy has been successfully implemented and has been well recognized in the group as well as in the ADNOC OPCOs. Some of our recruits who had joined us as Junior Engineers are today working in management positions, in different areas of operations, not only in Total but also in the ADNOC Group.
Assessment of Reservoir Quality and Maturity using Near-Real Time Surface Measurements: Diyab Source Rock In Abu Dhabi
Authors: Ali H. , Bondabou K. , Van Laer P. , Baig M. Z. , Raina I. , Dasgupta S. , Ammar M. , Dmello A. M. , Khan S. 
Published: November 2017

Abstract
Estimating reservoir potential and placing the well in appropriate zones for production can be complex and challenging in an unconventional play. Diyab source rock located in the United Arab Emirates close to Abu Dhabi is an example of such a complex unconventional. Rise in unconventional exploration is mainly driven by advanced and improved technology. One such advancement in technology is the use of advance surface measurements in unconventional plays at well site which being comprehensive reduces interpretation uncertainty; enabling fast near-real time decision making.
Some key inputs in estimating reservoir potential of a source rock play are fluid type, rock texture, lithology, Total Organic Carbon and maturity. Reservoir fluid quality assessment in near real time through compositional fingerprinting of lighter alkanes (C1 - C5), heavy components (C6 - C8), aromatic components (C6H6, C7H8 and MCC6) and non-hydrocarbon components (Helium and CO2). Advanced cuttings characterization at the well site provided minerology quantification using XRD and XRF, texture interpretation using high resolution digital imaging. TOC was measured using the combustion method. Maturity was estimated using a novel technique of diffused reflectance Infrared Fourier spectroscopy.
Fluid composition analysis results were used to characterize reservoir fluid type while the rock measurements were used to identify rock litho-facies units. Two main reservoir fluid types were identified in the Diyab source rock. Quantitative surface measurements were available prior to any downhole well logs or lab analysis results. Fluid type analysis was used to aid in the planning of the well logging and core analysis program. Fluid type results were later validated using core measurements. Surface measurements of mineralogy and TOC were compared to the log analysis and core analysis results. An excellent match between the two was observed. Over the interval where core was not available, surface measurements enabled calibration of log interpretation results which were affected due to complex mud additives. Maturity estimation using diffused reflectance infrared Fourier spectroscopy technique was compared to the Vitrinite reflectance (where available) and Bitumen reflectance measurements. A good match was observed between the two.For the first time in Abu Dhabi, a unique workflow of advance surface measurements were adopted to provide near-real-time reservoir fluid composition, quantitative total organic content and maturity assessment in unconventional plays; which enabled us to carry out reservoir quality assessment in the Diyab source rock.Maturity assessments while drilling on cuttings were first ever done in Abu Dhabi.Advance cutting measurements were used in designing core analysis strategy
New Approach to Chemical Diversion Using Biodegradable Particulates and Fibers in Matrix Acidizing: Kuwait Case Studies
Authors: Al-Othman Mohammed , A-Matrouk Yousef , Ahmed Zamzam , Ashkanani Meshari , Buhamad Ali , Al-Dousari Mohammad , Ahmed Abdul-Samad , Fidan Erkan , Mahmoud Wael , Liu Hai , Salem Abrar , Nikolaev Max 
Published: November 2017

Abstract
Heterogeneity across the producing interval is typical in oil and gas wells; it is rare to find uniform production distribution or fluid injection across a substantially long interval. Hence, diversion during matrix acidizing is critical, especially if the downhole pressure and/or temperature are high.
In two Kuwait Jurassic fields, two wells were completed in an over 100 ft producing interval across a carbonate reservoir. Reservoir temperature is 280°F, and the estimated reservoir pressure is 11,000 psi. Multiple matrix acidizing trials to enhance well productivity have been performed with conventional diversion techniques and, as indicated by the surface pressure response, were not effective. This requires an adequately engineered near wellbore diversion system that can overcome the challenge of these bottomhole conditions and form a uniform production distribution across a substantially long heterogeneous interval.
A new methodology was applied in two Jurassic wells that combined a multimodal blend of biodegradable particulates and fibers as a chemical diverter, and emulsified acids as main fluids for a matrix stimulation. In each diversion stage, the change in surface pressure ranged from 800 to 1,000 psi after the diversion pill hit the perforation tunnel. Moreover, a clear signature of diversion was demonstrated in the instantaneous shutin pressures. In another Kuwait field, the diversion pill was tested by using injectivity logging tests to monitor the changes in injectivity across the perforated interval during an acid fracturing treatment in comparison to the earlier injection profile. A remarkable change in injection was observed and a total of 80% change in the injection profile was quantified from before and after the diversion.
The diversion pill is relatively small in volume and is easy and safe to handle. Fibers help to maintain the carrying capacity and allow safe landing of the biodegradable material to the formation face. Only a few barrels are required to plug the opened or stimulated interval, and the method allows the following stimulation stage to treat the subsequent interval.
The first well revealed a 330% and 110% production increase in gas and oil rates, respectively. The production was set as one of the highest producers in the field. The second well yielded a 320% increase in total production, which set the highest record for the field. The new method is proved to be highly effective in terms of wellbore coverage, and highest production records in the field after matrix acidizing treatments.
Integration of Pressure Transient Tests in Fracture Characterization in North Kuwait Carbonate Reservoirs
Authors: Lamine S. , Richard P. , Steen E. Van , Pattnaik C. , Narhari R. , LeVarlet X. , Dashti Qasem 
Published: November 2017

Abstract
The North Kuwait Carbonate (NKJG) reservoirs are currently under development by KOC (Kuwait Oil Company). In addition to the matrix heterogeneity, natural fracturing poses extra challenges for the optimization of the field development planning. The presence of open, connected fractures presents opportunities for infill drilling but increases the risk of water invasion and drilling related issues. Numerous fracture modelling studies have been supporting both appraisal and development strategies of the fields.
The translation of the field observation and detailed fracture characterization using static BHI (bore hole image) and core data yields a series of geological concepts. These concepts capture end members of the spatial distribution of the major conductive features and provide a range of realizations for the geometrical extent of the fracture zones. Given the large uncertainty in the dynamic properties of the fracture; pressure transient analysis (PTA), complemented by core data, has proven to be key in narrowing the range of fracture equivalent permeabilities and porosities that are carried forward in the history matching step.
This paper focuses on illustrating the integration of different aspects of Pressure Transient Analysis data to pre-condition the discrete fracture network (DFN) model realizations.
Comparison between KH from well test and log data allows to discriminate fractured from matrix wells. Dedicated sector models around fractured wells are built to assess the impact of the matrix, faults and fracture properties on the transient pressure response. Numerical simulations are conducted directly on the static model with the fractures explicitly captured as discrete surface features. For each DFN configuration, a sensitivity analysis of the fracture properties is performed and the characteristics of the resulting pressure derivatives are then compared against the well test data to select the plausible realizations that honor both geological and flow data.
In this paper, a series of examples demonstrating the application of the methodology are presented for different areas of the field.
Contribution of Tidal Analysis to Reservoir Monitoring - Field Case Study in a Fractured Reservoir Offshore Abu Dhabi
Authors: Faidouzi Mohamed Mehdi 
Published: November 2017

Abstract
Offshore reservoirs are subjected to pressure loading from the ocean tide. The resulting pressure fluctuation, notably its amplitude and phase, provides valuable information about the formation compressibility and heterogeneity. The purpose of the present study is twofold: first to propose a method for calculating tidal efficiency from harmonic analysis of regional tide stations and detrended bottomhole pressure, and second to compare the compressibility from tidal analysis to that obtained from rock mechanics measurements and material balance. This case study is on a fractured oilfield for which matrix laboratory measurements alone cannot capture the large scale formation compressibility which is driven by the .fracture distribution.
This paper will show how, in the absence of seabed pressure measurement, a synthetic diurnal tide can be simulated by interpolating the harmonic constituents of neighbouring tide stations. A new procedure combining Savitzky-Golay filter and cubic splines gave satisfactory results to filter out the tidal signal residual from the reservoir transient response. The tidal efficiency and pore pressure compressibility, computed through history for several wells, showed a clear correlation with the fracture tendancy. Also fluid effects, caused by higher water saturation in downdip wells or gas breakthrough, produce a clear signature on the tidal efficiency.
Enhancing Sustainability in Acid Gas Flare Operations
Authors: Dutt Indrajit , Hassan Yasser 
Published: November 2017

Abstract
Facility designs consider common acid gas flare for multiple plants operating in the complex, based on cost optimization considerations. Such designs involve common Flare KOD, which is difficult to maintain, as multiple plant shutdowns are not feasible during shutdown planning. Common stand-by Flare KOD with suitable isolation provisions from different plants’acid gas headers ensures timely maintenance and thus enhances the sustainability of the Acid Gas Flare Operations.
Due to presence of high levels of acid gases with moisture, acid gas flare streams tend to be highly corrosive. This poses safety threat to operating personnel, by loss of containment of toxic gas from vessel rupture or possible toxic gas leaks through KOD flanges. This situation was encountered in one of the GASCO operating complexes, where 2 existing plants shared a common flare KOD and a third existing plant via a different KOD was connected to the same acid gas flare.
Original design envisaged maintenance of the acid gas flare by inter-connection with one of the existing hydrocarbon flares but safe inspection of the acid gas flare KODs could not be conducted. Non-intrusive ultrasonic scanning indicated severe corrosion in one of the existing KODs at various positions. However, due to absence of proper isolation facilities, internal inspection / replacement of the existing KODs was not possible without a total shut-down, which was not permissible.
To overcome the problem, a standby flare system was studied to improve operational and maintenance flexibility, but was not implemented due to costs that were considered excessive. Instead, a more cost-effective solution based on installation of a standby KOD was implemented to address the critical Process safety issue. For installation of the new facility without any plant shutdown, several hot taps were required on the flare header.
Implementation of the Standby KOD costed less than USD 8 Million, substantially less than the estimated cost of around USD 100 Million for Standby Flare project, while providing the desired level of operational and maintenance flexibility.
Also, subsequent to the installation of the Standby KOD, an existing flare KOD, experiencing severe wall thinning due to corrosion, could be replaced without any plant shutdown. Reliability of existing acid gas flare KODs to resist toxic gas leaks has now improved with routine internal inspections.
Major Energy Saving and Revenue Generation Initiatives in GASCO Bu Hasa NGL Plant in 2016
Authors: Saleh Ahmed 
Published: November 2017

Abstract
This presentation will discuss Four Energy Efficiency initiatives were taken in 2016 in one of the biggest NGL Producing Plants in the UAE (GASCO-Bu Hasa).
They are: C3+ Recovery Enhancement: Increased the discharge pressure of HP compressor (2K-103/203) by 1 bar over the current operating pressure of 27.2barg. As an output, overall C3+ recovery increased by 0.3-0.4wt% depending on consistent operation at test run conditions.Utilizing 36" HP Line for Residue Gas: 36" BHGP line designed for diverting the excess HP gas, this was innovatively utilized for diverting excess Lean Gas and avoiding residue gas flaring.Savings through Advanced Process Control (APC): Advanced Process Control (APC) was implemented in Bu Hasa in 2009. During Jan & May-2015 tuning exercise initiated for all APC Controllers through GASCO in-house team.Savings through Internal & External Leak Survey: GASCO Bu Hasa NGL plant has taken the proactive approach to reduce hydrocarbon leaks by implementing an Internal and External Leak Detection and Repair Program.
A Novel Non-Acid Stimulation in Deep HPHT Naturally Fractured Gas Sandstone
Authors: Jianxin Peng , Mingguang Che , Guoqing Zou , Jiangyu Liu , Liao Wang , Rui Gao , Juan Xie , Leifeng Meng , Runqiang Fan 
Published: November 2017

Abstract
KeShen gasfield is a low matrix permeability intensely naturally fractured tight sandstone reservoir in Kuqa gasfield of Tarim basin, West China, with the characteristics of high-pressure 120MPa-140MPa, ultra-depth 6700m-8000m, high temperature 160°C-190°C, and long lateral 200m-300m. A non-acid stimulation was trialed in five wells and the post-production was surprised.
During drilling, a large number of barite is used to increase mud weight, and some calcium carbonate is used to avoid reservoir damage, But the damage is usually serious because of hundreds of tons of mud leakoff and the drilling fluid cakes. A non-acid cheating agent was trialed for removing the damage and increasing the production, based on the cheating mechanism, the divalent metal ions will be chelated by cheating agent, and barium or calcium ions will be preferentially chelated.
The non-acid cheating agent is an alkaline chelate with density 1.03g/cm3, the dissolving capacity of chelating barium ions is increasing by the chelating agent concentration and temperature. The concentration is usually from 25% to 30%, and the capacity of chelating barite ions is about 12.5-12.8g/L at the temperature of 170 °C. The reason for using chelating agent to remove the damage is that fresh acid and reacted acid can make strong corrosion to tubing string in the process of acidizing in high temperature reservoir. On the condition of 140 °C, the laboratory experiments indicate that the corrosion rate of fresh acid and the residual acid is 17.4g/ (m2·h) and 3g/ (m2·h) respectively, however, there is essentially no string corrosion observed when using the chealting agent for removing the damage. The non-acid cheating agent was trialed for five Wells. The general pumping rate is from 3.0 m3/min to 4.4m3/min, and the total volume of cheating agent is about 400m3. The gas post-production is about from 60×104 to 70×104m3/d, similar to that of adjacent wells to which acidizing or hydraulic fracturing are applied. The flowback fluid of the non-acid stimulation wells is tested, the results indicate that the maximum content of barium sulfate is 3200 mg/l, and the maximum content of calcium ion is 4382mg/l.
The non-acid stimulation is an effective method for high temperature intensely naturally fractured gas sandstone, no tubing corrosion.
First Attempt of the Multi-Well Simultaneous Steam Stimulation for Offshore Heavy Oilfield: A Case Study
Authors: Han Xiaodong , Liu Yigang , Wang Qiuxia , Zou Jian , Liu Hao , Wang Hongyu , Zhang Xiang , Wei Bing 
Published: November 2017

Abstract
Limited by platform space and equipment capability, thermal fluid injection was conducted for each individual well during heavy oil development with cyclic steam and flue gas stimulation in NB35-2 Oilfield. The single well injection mode results in severe gas channeling from injection well to adjacent production wells caused by areal pressure imbalance and high development cost. Measures must be taken to improve the recovery effect and economic benefits, especially in the low oil price environment.
The idea of multi-well simultaneous steam stimulation for offshore heavy oilfield was proposed and applied for actual practice in NB35-2 Oilfield. According to reservoir simulation results, formation pressure distribution could be much more even when thermal fluid was injected into the formation from different wells simultaneously. Besides, the overall developing cost could be greatly reduced by lowering the integral operating cost. For further controlling the gas channeling, the foam and temperature-sensitive gel were also used for gas channeling plugging. Based on the capacity of current steam and gas generator, two thermal wells were selected for field trail.
During the simultaneous steam and flue gas injection process of well X1 and X2, no gas channeling phenomenon occurred from the injection wells to adjacent wells which means that no negative impact on the production wells was induced by the injection operation. And the multi-well simultaneous steam stimulation combined with chemical plugging has displayed positive effects in controlling gas channeling. The daily oil production rate of these two wells were increased from 28.77 m3/d to 38.87m3/d, and 23.68 m3/d to 35.71 m3/d, respectively when compared with its value before steam injection. The predicted overall incremental oil production amount is about 5250 m3, and the period of validity is about 180 days. More importantly, compared with the operating cost of previous single well injection mode, the commuted operating cost of the multi-well simultaneous stimulation for one single well is greatly decreased by about 45 % and this kind of operating mode will surely bring more economic benefits.
This is the first time that multi-well simultaneous steam stimulation for offshore heavy oilfields is proposed and put into field trial. The favorable application result indicates that this technology could provide a useful guidance for the high-efficient heavy oil exploitation of offshore oilfield.