bluuebunny/crossref_metadata_2025_split huggingface dataset:
Production Engineering Specialist Program is Helping Saudi Aramco to Meet Technical Challenges in Upcoming Mega-Projects
Authors: Yateem Karam S. , Warsi Syed , Alsyed Samih M. 
Published: December 2014

Abstract
In a quest to maintain and enrich its employees’ knowledge base to not only have competitive edge but also prepare the workforce to handle the ever increasing complexity in hydrocarbon extraction and production, today's energy companies employ training programs to equip their experienced personnel with skills that can be utilized to effectively handle challenging projects. Saudi Aramco, among many technical specialist programs, has also developed an all-encompassing training program for experienced professionals, which upon completion will allow the individual to perform duties as a subject matter expert (SME) in production engineering related job skills. This accelerated Production Engineering Specialist Program (PESP) is designed to make the transition from a young professional to an expert in a specific subject with a customized approach to his background and tailored to his future career path.
PESP is applicable to young engineers after attaining five years of post-university experience, exposing them to various facets of production engineering and focusing on an explicit specialty. The Program incorporates seven specialties, all related to Production Engineering. These specialties are Stimulation, Well Completion, Electrical Submersible Pumps, Well Intervention, Well Treatments, Production Optimization and Intelligent Field. Completion of the Program is time-based but rather mandated by completing predetermined tasks in all aspects of the respective specialty and customized to the participant's background.
The program has yielded several graduates since its inception. It is a proven successful program, which has allowed PESP graduates to move around the company in assignments, targeted to provide support expertise in their related specialty in challenging situations. The paper will provide details of the PESP structure, typical Individual Development Plans (IDPs) for these seven specialties and how PESP graduates can help the company to meet the technical challenges for upcoming mega-projects by utilizing their expert knowledge as SMEs. PESP has a broader scope to build an interchangeable pool of SMEs that can minimize the need and dependence of acquiring knowledge from service companies and in addition be able to train future generations of young professionals.
Water and Gas Control in Naturally Fractured Carbonate Reservoirs: Development of a Novel Polymer Gel System with Foaming Properties
Authors: Vasquez Julio , Lewis Chris , Eoff Larry 
Published: December 2014

Abstract
Excessive undesired fluid production of water or gas can limit the economic life and profitability of hydrocarbon reservoirs. A variety of techniques for controlling water production have been attempted within the oil industry, including mechanical and chemical treatments. Chemical treatments can become more challenging when applied in reservoirs with either natural or induced fractures. More specifically, placement control becomes a critical factor, particularly within highly fractured and depleted reservoirs. This paper presents the development and optimization to further improve a widely used organically crosslinked polymer gel system by adding foaming properties to the innovative fluid system. Referred to as a foamed conformance polymer (FCP) in this work, the system can improve placement in naturally fractured carbonate formations for water and gas control applications.
The standard (nonfoamed) organically crosslinked polymer system is based on a copolymer of acrylamide and t-butyl acrylate (PAtBA) crosslinked with polyethyleneimine (PEI). This FCP system can be foamed up to 70% v/v quality to be applied within a wide temperature range (40 to 350°F) with little to no effect on gelation time, providing a stable foam that maintains sealing properties. This paper discusses the following parameters: (1) FCP advantages and considerations, (2) FCP system components to develop foam properties, (3) FCP performance testing to optimize foaming properties up to 70% v/v quality at elevated temperature, and (4) sealing capabilities of the FCP system. Addition of foaming properties to this conformance polymer gel system adds the following benefits: (1) improved placement in depleted, naturally fractured or fissured carbonate reservoirs, (2) reduced hydrostatic pressure (density can be lowered to ~2.4 lbm/gal), allowing better control of surface pressure while placing the treatment into the targeted zone, (3) improved ability to fill fractures and displace reservoir fluids by providing a system with fluid-loss control properties, and/or (4) diverting fluid properties for optimum coverage when targeting long intervals. The FCP produces a high-quality, stable foamed solution to help effectively seal natural fissures and fractures for reduced flow of unwanted water and/or gas.
Subsidence Evolution of the Musandam Peninsula & Subsurface Architecture of the Pabdeh Foreland Basin
Authors: Aidarbayev Sanat , Ali Mohammed Y. 
Published: December 2014

Abstract
Surface and subsurface geology of the Musandam Peninsula recorded a tectonostratigraphic evolution of the northeastern Arabian Plate since the late Permian. In order to quantitatively determine this evolution, backstripping method has been applied to two exploration wells located within and around the Musandam Peninsula. The backstripping technique uses stratigraphic data extracted from the wells and quantitatively determines the depth that basement would be in the absence of water and sediment loading. As a result, the tectonically-driven subsidence data allows us to determine basins developed within the study area and their driving-mechanisms to form.
The tectonically-driven subsidence data from the wells recorded development of a rifting and two flexural foreland basins. The rifting episode formed in response to a continental breakup and opening of Neo-Tethys Ocean, approximately from ~ 185 to ~ 93 Ma. Heating and stretching of the continental lithosphere at the time of the rifting caused the lithosphere to subside. After this rifting event, the tectonic subsidence curves indicate that the studied area was subjected to evolution of two foreland basins after two uplift events happened around ~ 93 and ~ 25 Ma. We refer these uplifts to the Late Cretaceous Semail Ophiolite obduction and the late Tertiary Musandam culmination, whereby both of them produced lithospheric loads on the top of the northeastern Arabian plate and led to a development of two foreland basins, Aruma (~ 80 to 25 Ma) and Pabdeh (~ 20 to present day), respectively.
With the rise of interest for unconventional resources, we have to better evaluate the essential petroleum system elements. Normally, the total subsidence (tectonically-driven plus sediment and water loading) is used to construct the burial history of a basin. Since the backstripping method is able to separate the tectonically-driven subsidence from the total subsidence, we can exactly pinpoint the deposition time of deep-water sediments which can act as a source rock or an impermeable seal. In addition, the tectonic subsidence curve was able to identify precise ages of two uplifts which mark the critical timing of potential structural traps and migration pathways for hydrocarbons.
EOR Options for Heterogeneous Carbonate Reservoirs Currently Under Waterflooding
Authors: Masalmeh Shehadeh K. , Wei Lingli , Blom Carl , Jing X. D. 
Published: December 2014

Abstract
Carbonate reservoirs in the Middle East are highly heterogeneous with complex porosity systems and mixed-wet matrix properties. These characteristics strongly affect reservoir performance under waterflooding. This paper concerns a highly layered limestone reservoir with various levels of cyclicity in properties and can be described at a high level as consisting of two main bodies, i.e., an Upper zone and a Lower zone with permeability contrast of up to two orders of magnitude. The main part of the reservoir is currently under waterflooding. Field observations show that injected water tends to channel quickly through the Upper zone along the high permeability layers and bypass the oil in the Lower zone. Past studies have indicated that this water override phenomenon is caused by a combination of high permeability contrast and capillary forces which counteract gravity forces.
In this paper we will investigate different development options for such heterogeneous mixed-wet reservoirs aiming at improving recovery from the Lower zone: 1- Optimized waterflooding with infill wells, 2- Novel EOR options designed to overcome the capillary forces and improve vertical sweep. The EOR options include (a) polymer-assisted solutions consisting of injecting polymer in the Upper zone and water or miscible gas in the Lower zone; and (b) surfactant assisted solutions (foam and enhanced gravity drainage).
The main conclusions of the study are: 1- Waterflooding is an efficient recovery mechanism for the Upper zone and tight well spacing is required to improve recovery from the Lower zone; 2- The EOR processes have the potential of improving recovery from the Lower zone; 3- The most attractive EOR schemes are the polymer-based options which, when compared to the optimized waterflooding/infill scenario, lead to much higher recovery, lower volumes of water injected and significantly less water cycling and the requirement of fewer wells. The polymer-assisted solutions also require injecting much lower polymer volumes compared to conventional polymer flooding. Simulation results show that the process(es) are robust to injection rates, vertical heterogeneity, well completions and a range of polymer viscosities.
Non-Deterministic Approach to Define a Robust Development Plan: a Complex Mature Carbonate Field Case Study
Authors: Barroso Viseras F. J. , Blanchais S. , Verdiere S. , Bouzarkouna Z. , Schaeffner A. , Jannes P. 
Published: December 2014

Abstract
As oil production demand increases, the industry as a whole faces the need to constantly renew its reserves by either discovering new fields or giving a second life to mature fields. The latter is particularly challenging for geoscientists and reservoir engineers. This paper presents a non-deterministic approach used to design a robust development plan for a complex mature carbonate field with more than a hundred wells and forty years of production history.
This innovative approach can be applied to any redevelopment project for uncertainty assessment and risk management.
The first step is a 2G&R synthesis performed by a multidisciplinary team to gather all the data, verify their consistency and assess the key heterogeneities and potential influential parameters to quantify the different production mechanisms. At this crucial stage, experimental design is extensively used. This synthesis enables a solid history-matched simulation case with an associated redevelopment strategy to be built efficiently. Secondly, the thorough knowledge of the field and the expected production mechanisms in the redevelopment phase are the key drivers to identify the most impacting static and dynamic parameters. These parameters are used as inputs for experimental design on both historical and redevelopment periods. Assisted History Matching techniques enable multiple simulation models honoring historical data to be found; the quality of these models is assessed by considering different objective functions. The history-matched models are then used to derive a reserves distribution for the project. Models outputs are combined to generate 3-D probability grids for properties such as oil saturation, in order to optimize the initial development plan and improve its robustness.
This study highlights the importance of a strong and consistent 2G&R synthesis. An in-depth understanding of the field, combined with Assisted History Matching techniques, leads to models that honor the long production history, enabling the development scenario to be optimized.
Production Optimization over 20% with Artificial Lift ESP Pilot Systems in Mature Oil Field, Case Study from Middle East
Authors: Aguilar Hector , Al Marzooqi Aref Ali , El Sonbaty Tarek Mohamed , Villarreal Leigber 
Published: December 2014

Abstract
This paper reviews the production optimization strategy of an artificial lift system that has been implemented in a carbonate reservoir in an Abu Dhabi onshore field. The adapted optimization technique assures the mitigation of the main challenges related to reservoir heterogeneities, in addition to completion design which has a significant impact on ESPs sizing, operation and optimization processes.
An integration approach of reservoir dynamic data and ESP performance was established as a guideline for ESP surveillance, diagnostic and targeting candidate for production optimization by implementing at least one of the possible solutions: (a) upgrading ESP-surface equipment, (b) anticipate WO for re-sizing & ESP Deeping jobs, (c) well design strategy review.
The result of this effort demonstrates the successful implementing of proposed solutions by enhancing the oil production by more than 20% in all separates pilot tests conducted in the field. The project success can lead the way forward for future ESP application in similar harsh down hole conditions.
Interaction Between Hydraulic Fracture and Natural Fracture - A New Prediction Model by Adaptive Neuro-Fuzzy Inference System (ANFIS)
Authors: Chen P. , Rahman M. M. , Sarma H. K. 
Published: December 2014

Abstract
Hydraulic-fracturing (HF) treatments have become an essential technology for tight gas field development. Tight gas formations often contain natural fractures (NF). In presence of NF, more complex fracture networks may form during the hydraulic treatment. The interaction between fractures may alter the way the hydraulic fracture propagates through the formation, causing a complex network of fractures, which can significantly influence the overall geometry and effectiveness of hydraulic fracture. The hydraulic fracture may cross, dilate or slip into the fracture plane upon its arrival at the natural fractures. Although there have been studies on investigation of the interaction between HF and NF, most of them cannot be applied reliably due to the inherent assumptions in the analytical formulation. In cases of laboratory studies, the limitation of the equipment could also be a factor. With this study a multi-ANFIS model is established to predict the interaction between HF and NF. The advantage of this model is that it is a data-based model. Therefore, as long as there are reliable data the model can work smoothly and easily, so that it can predict the interaction in real time. Results show that the dilation and slippage will be more likely to occur when the approach angle is very low. Whereas, in the case of higher differential horizontal stress, it is more likely that the cross interaction will happen. The significance of this work is to help to predict the interaction between HF and NF, thus optimizing the hydraulic-fracture treatment design parameters in a naturally fractured tight gas reservoir. Insightful parametric sensitivity analyses will also be presented. This model could also be used to study the potential of the deep UAE gas sands, which are naturally fractured.
Wellbore Monitoring in Carbonate Reservoirs: Value of DTS in Acid Stimulation through Coiled Tubing
Authors: Gorgi Sam , Medina Eber , Gleaves Jorge , Acuña Juan , Perera Luis , Rodriguez Miguel 
Published: December 2014

Abstract
In acid matrix stimulation, the correct placement of the injected fluids is essential. Several diversion and placement techniques are often applied to obtain the desired fluid placement (Glasbergen and Yeager 2010). Distributed temperature sensing (DTS) and coiled tubing (CT) pressure, temperature, and collar locator tools were used to monitor the fluid placement and effectiveness of the diversion process.
Real-time monitoring was required as part of the overall reservoir management strategy for the Tecominoacán 705 well. The CT service provided ideal conveyance for DTS in this highly deviated and depleted well. In a distributed-temperature survey, the fiber optic served as the sensing element, and combined with CT conveyance and pressure/temperature/collar locator tools, enabled continuous wellbore temperature monitoring across the entire horizontal while pumping a stimulation treatment through an annular space consisting of acids and diverters. It also allowed real-time decision making based on the actual measured injection profiles.
This well was highly deviated in a carbonate reservoir, completed with 675 m of 4 1/2-in., 12.7 lb/ft liner and swell packers, with 150 m of tubing conveyed perforating (TCP) perforations distributed in six intervals. The DTS combined with CT tools provided accurate monitoring of the stimulation treatment, which was pumped through the annulus between the production tubing and CT. With the DTS service, it was observed that the stimulation fluids were injected only at the heel of the well, which was acting as a thief zone as a result of the presence of highly conductive natural fractures. Several stages of diverters were pumped to attempt to divert acid from the heel to the tip of the well, without success. The decision to cancel the final acid stages saved USD thousands in fluid costs. Mixing the acid on-the-fly using special blending equipment allowed the optimization of resources based on real-time decisions influenced by the DTS injection analysis.
From Horizontal to Vertical Leadership Development
Authors: Flahive Tadhg 
Published: December 2014

Abstract
We are now living in a VUCA (volatile, uncertain, complex, ambiguous) world. The nature of challenges faced by current leaders is constantly evolving while the methods most organizations are using to develop leaders are generally staying the same. The renowned American Business Theorist, Chris Argyris, used the analogy of single versus double loop learning. In the former adjustments are made to existing techniques. The latter involves changes to the assumptions and thinking upon which programmes are built. For organizations to survive and prosper in this new world, double loop learning is essential.
Leaders now have to do more with less. More adaptive and complex thinking abilities are required. There is a need to grow bigger minds. "There are no boundaries anymore" (Jeff Barnes, Head of Global Leadership, General Electric). New adaptive leadership competencies, skills, abilities and attributes are now needed in interconnected global work environments. A paradigm shift has to ensue and be manifested in both the constructs and delivery of leadership programmes. "Future generations will be living in a world that is very different from that which we are accustomed to. It is essential that we adapt ourselves for this new world" (His Highness Sheikh Zayed Bin Sultan Al Nahyan, founding rule of the UAE).
This paper will provide clear evidence of how one of ADCO's main internal leadership programmes "Leading People Performance" (LPP) has re-aligned and re-focused its content along four leadership development trends: transfer of ownership to the individual; innovation and technology; collective leadership; alignment to work context.
The paper will first look at the reasons why many leadership programmes don't work. This will be followed by a clear differentiation between horizontal and vertical leadership development. A detailed overview of the LPP programme will be presented. The final section of the paper will provide examples of how LPP incorporates elements of vertical leadership development within the aforementioned four leadership development trends.
Abnormal Reservoir Property Changes of Lower Cretaceous Carbonate, Gas Reservoir Onshore Abu Dhabi, UAE
Authors: Al Hashemi Hussain H. , Masoud Rashad , Al Ammari Khalid , El Gohary Mohamed , Moen-Maurel Laure 
Published: December 2014

Abstract
Carbonate Reservoirs are well known for their heterogeneity in terms of porosity and permeability. In this field case from UAE onshore a sharp degradation of petrophysical quality was noted at the gas-water contact, in relation to diagenetic cementation, and led to an independent modelling for the aquifer, as well as an independent modelling of the reservoir with a data filter for the gas pool only. A merge of the 2 grids was then performed.
In this field a major bias on well data distribution from crest to aquifer affects the geostatistical histogram evaluation: wells are concentrated in the crest down to mid-flanks while there are few wells from mid-flanks to the aquifer. Consequently distribution histograms of petrophysical data from the whole model should not respect well data histograms (whether, core-, log- or cell-derived).
The methodology of separating gas and aquifer modelling, and of separating well derived histograms from model-derived ones led to the following results:
– Better capture of the reservoir degradation with depth in the gas pool, – Better capture of the sharp degradation break in the aquifer.
This paper is focusing on the methodology of how to build two separate models in the gas pool and the ‘aquifer for each petrophysical property and how to combine them in one property model to honour reservoir heterogeneity.
Integration of all data at all scales and constant QC between database sources (logs, cores, seismic, dynamic history) were the means to produce a geomodel capturing the key heterogeneities of the reservoir, those with major impact on fluid front migration during production.