bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New Approach for Optimization and Uncertainty Assessment of Surfactant-Polymer Flooding
Authors: Nguyen Ngoc T. , Chen Zhangxin , Nghiem Long X. , Dang Cuong T. , Yang Chaodong 
Published: December 2014

Abstract
Surfactant-Polymer (SP) flooding has become an attractive Enhanced Oil Recovery (EOR) method. Defining chemical concentrations, chemical types and an injection schedule, according to geological features of a reservoir and well pattern, is key to making decisions for reservoir management.
In this paper, we introduce an innovative approach for EOR optimization under geological uncertainty by integrating a reservoir geological property modelling and a robust optimizer. Multiple reservoir realizations are generated automatically by geology-driven modeling software and sent directly to an optimizer to analyze the effect of single or multi-parameters on objective functions such as cumulative oil production and net present value (NPV). Clay minerals play an important role in chemical flooding, but it is rarely included in the reservoir simulation. In this study, the distribution and proportion of clay are investigated in terms of facies and its relationship with porosity and permeability for a sandstone reservoir. Different facies and petrophysical properties are geostatiscally generated in a geologic manner that significantly improves the quality of history matching and optimization processes.
It is found that SP flooding has the highest oil recovery factor in comparison with waterflooding, polymer flooding and surfactant flooding, and it demonstrates good performances even in high clay content reservoirs. The optimal formulation of SP and polymer slugs and injection schedule were proposed. The effect of clay content in cumulative oil and NPV were addressed, in which the more clay content is the lower NPVs obtain. A comprehensive geological uncertainty analysis has been performed for: (1) facies distribution only; (2) facies distribution and proportion. The results indicated that NPV uncertainty is less than 2.25% for (1) and about 4.18% to 5.68% for (2).
The proposed optimization approach could be effectively applied to tertiary EOR techniques in various reservoir conditions under geological uncertainty. By integrating geological software, reservoir simulator and robust optimizer, it serves as a powerful tool for design and optimization of these processes.
SP flooding is definitely a complicated process, therefore, an innovative modeling and optimization approach for SP flooding described in this paper is needed to improve the prediction of process performance.
Demonstrating the Potential of Low-Salinity Waterflood to Improve Oil Recovery in Carbonate Reservoirs by Qualitative Coreflood
Authors: Nasralla Ramez A. , Sergienko Ekaterina , van der Linde Hilbert A. , Brussee Niels J. , Mahani Hassan , Suijkerbuijk Bart M. , Al-Qarshubi Ibrahim S. , Masalmeh Shehadeh K. 
Published: December 2014

Abstract
Low salinity waterflood (LSF) is a promising improved oil recovery (IOR) technology. Although, it has been demonstrated that LSF is an efficient IOR method for many sandstone reservoirs, the potential of LSF in carbonate reservoirs is still not well-established as only a limited number of successful coreflood experiments are available in the literature. Therefore, the aim of this study was to examine the oil recovery improvement by LSF in carbonate reservoirs by performing coreflood experiments.
This paper proposes an experimental approach to qualitatively evaluate the potential of LSF to improve oil recovery and alter the rock wettability during coreflood experiments. The corefloods were conducted on core plugs from two Middle Eastern carbonate reservoirs with a wide variation of rock properties and reservoir conditions. Seawater and several dilutions of formation brine and seawater were flooded in the tertiary mode to evaluate their impacts on oil recovery compared to formation brine injection. In addition, a geochemical study was performed using PHREEQC software to assess the potential of calcite dissolution by LSF.
The experimental results confirmed that lowering the water salinity can alter the rock wettability towards more water-wet, causing improvement of oil recovery in tertiary waterflood in plugs from the two reservoirs. Furthermore, seawater is more favorable for improved oil recovery than formation brine as injection of seawater after formation brine resulted in extra oil production. This demonstrates that the brine composition plays an important role during waterflooding in carbonate reservoirs, and not only the brine salinity. It was also observed that oil recovery can be improved by injection of brines that cannot dissolve calcite based on the geochemical modeling study. This implies that calcite dissolution is not the dominant mechanism of IOR by LSF.
To conclude, this paper demonstrates that low-salinity waterflood has a good potential as an IOR technology in carbonate reservoirs. In addition, the proposed experimental approach ensures the verification of LSF effect, either it is positive or negative. However, more work is required to further explore the most influential parameters affecting LSF response and explain the dominant mechanisms.
Challenges and Learning from Developing Deep High Pressure Sour Reservoirs in Southern Oman by EOR MGI
Authors: al-Hadhrami Abdullah , Jabri Abdullah , Alawi Hamoud , Proot Michael , Schulz Ralf , Barwani Shihab , D'Amours Kevin 
Published: December 2014

Abstract
The Sour Cluster is located in the south of the Sultanate of Oman. Since the first oil discovery in 1997, a successful exploration drilling campaign was carried out in the Cluster, resulting in the discovery of several carbonate stringer oil and gas reservoirs. Approximately half the gas volumes are contained in a gas condensate field. This field will be developed along with the other oil reservoirs in the cluster and will export gas to market as well as provide a source of make-up gas for the miscible gas injection operations.
In phase 1 of the development (normal depletion), the wells were routed to the existing station-B via the Early Development Facility (EDF). These facilities consisted of a number of remote manifolds, a 70 km multiphase pipeline to station-B and a new oil and gas compression train at station-B. Whilst the field was depleted via station-B, design and construction of the new plant (phase 2) progressed.
First production from phase 2 commenced 10 April, 2012, some 3.5 years after the target first oil date. Despite the delayed start, this first oil milestone is considered a commendable achievement given the significant challenges faced by the project team during the execution phase. Building a facility to handle the extreme mixture of high pressure, sour corrosive fluids and gas contained within the sour reservoirs is a technical step-out for PDO, let alone the oil industry in general.
The establishment of the new Production Station (Station-H) now provides the infrastructure for long term development of the area and a number of follow-on projects which will make use of these facilities are either already in operation (Phase 3) or in execution(Integrated Phase 4). Learning from phase 2 has been taken onboard in the design of these follow-on projects and the area will deliver robust value to PDO / Oman for generations to come.
This paper will outline some of the key challenges that were overcome by the design and project execution teams on the phase 2 project and how lessons learned were taken onboard to facilitate project delivery of the extended larger MGI development for follow-up phases and in similarly challenging projects in PDO.
Micro Rhombic Calcite of a Giant Barremian (Thamama B) Reservoir Onshore Abu Dhabi - Clumped Isotope Analyses Fix Temperature, Water Composition and Timing of Burial Diagenesis
Authors: Vahrenkamp V. , Barata J. , Van Laer P. J. , Swart P. , Murray S. 
Published: December 2014

Abstract
Micro porosity associated with micro-rhombic calcite provides volumetrically the largest pore volume in Middle Eastern Cretaceous carbonate reservoirs. With progressing reservoir development and depletion of macro-pore systems the low permeability micro pores have ever increasing importance as host to remaining hydrocarbons and for reservoir performance. A new technique is presented – Clumped Isotope Thermometry – which yields significant new insights on burial depth, timing of diagenesis and the nature of the diagenetic fluids. This in turn helps to better understand the widespread distribution of micro porosity in Abu Dhabi reservoirs.
The genesis of micro-rhombic calcite has previously been placed into the shallow burial realm under the influence of meteoric or marine pore waters (Budd, 1989; Moshier, 1989) using oxygen stable isotopes and petrographic observations. However, the interpretation of oxygen isotope data is limited by the fact that the isotopic composition of calcite minerals is determined by two independent factors: the isotopic composition and the temperature of the precipitating water. The new analytical technique of clumped isotopes has established a way to independently determine one of the variables (temperature) thus allowing the other (water composition) to be fixed. The new technique has been applied to 15 samples from three cores of a giant Abu Dhabi reservoir. Samples are from the Barremian Thamama B reservoir unit. Stable isotope data exhibit a normal range for Thamama B calcite (δ13C: 2.8‰ to 3.9‰; δ18O: 4.6‰ to 5.9‰). Clumped isotope analyses indicate a most likely precipitation temperature of 65°C to 72°C and an isotopic composition of precipitating waters of 3.3‰ to 4.9‰ δ18O. Using a well calibrated basin model the temperature range places the depth of diagenesis between 0.65 km and 1.1 km and the timing of diagenesis into the Late Cretaceous (Turonian to Campanian). This coincides with the subsidence of the eastern Arabian plate margin caused by the opduction of oceanic crust (Semail ophiolite and associated marine sediments). The heavy oxygen isotopic composition of the diagenetic water of 3.3‰ to 4.9‰ δ18O corroborates a burial setting for diagenesis. Results imply that diagenesis was driven by a regional east to west burial flow system driven by compaction and convection with likely significant implications for the regional distribution of porosity & permeability.
CO2 Rich Natural Gas Conditioning Technologies: Comparison Study
Authors: Farges O. , Fränkie S. , Linicus M. , Terrien P. 
Published: December 2014

Abstract
Nowadays, a growing interest is shown for CO2 rich natural gas fields. Especially South East Asia, Australia and South America are regions where the exploitation of such gas fields is investigated.
A wide range of proven technologies for CO2 removal exists, from the traditional amine units, membrane systems including one or multiple stages, to newly developed cryogenic technologies and combinations of the above. These technologies need to be adapted and optimized providing technically and commercially viable solutions to gas field operating companies for the conditioning of such a low caloric natural gas.
This paper presents the results of a study comparing the most promising natural gas conditioning technologies considering various process parameters like CO2 and hydrocarbon feed content, plant capacity, treated gas specification, hydrocarbon recovery requirement and the potential CO2 valorization application (e.g. enhanced oil recovery (EOR)). Air Liquide Global E&C Solutions has a unique position in performing such a technology comparison as a technology provider for all bricks. Inhouse and commercial tools were used in order to optimize each technology brick independently as well as to intregrate the bricks together.
Various process schemes have been studied for natural gas feedstocks containing up to 60 vol% CO2. This paper comprises general process description of the conventional amine and membrane setups as well as more information about the innovative cryogenic solution proposed herein. The total costs of ownership for the different processes have been evaluated taking into account capital and operational expenditures as well as the hydrocarbon recovery of the applied processes.
Although the optimum solution strongly depends on the specific project's parameters, some general trends and conclusions can be derived from the results of the study: the combination of membranes with cryogenics is the most suitable solution in case of high CO2 containing feed stocks and if the CO2 product is used for EOR applications, means a pure CO2 product delivered at high pressure. Amine wash and hybrids of amine wash and membrane seem to be favorable at low to medium CO2 containing feed stocks and if the CO2 product shall be supplied at low pressure to battery limits. Beyond that, the paper also comprises conclusions and recommendations taking into account the other project and process parameters and their respective operating ranges.
Paper Title: Workforce Nationalization in Emerging Oil and Gas Markets
Authors: Paydar Masoud 
Published: December 2014

Abstract
In oil-rich markets from Africa to the Middle East, recruiters and employers are reacting to government pushes to see a higher proportion of the workforce made up of native-born workers. It's become the responsibility of global organizations to support the local workforce and ensure integration of the local and expatriate talent. Government-owned National Oil Companies (NOCs) demand heavy investment and commitment in the development of educational institutions, workforce nationalization, and investment in foreign countries' critical infrastructure.
International energy companies utilize Workforce Nationalization programs as they expand operations into foreign countries. These programs employ nationals in oil and gas projects, making them stakeholders, as their participation adds value to their local economies. The programs also enable Multinational energy companies to integrate into the communities they operate in.
For Workforce Nationalization programs to be effective, companies need to provide the necessary technical, safety, and cultural training to develop people for operational roles. Post-secondary institutions are responding to this market need for customized training, which is delivered offshore or in-country. Training programs leave a positive impact by contributing to the overall economic development of the country, and by providing individuals the opportunity to not only enter into the workforce but also to develop a career path and to expand their cultural horizons.
Unified Communication and Collaboration from office to Rig
Authors: Moussa Mohamed Samir 
Published: December 2014

Abstract
The aim of this paper is to demonstrate the experience of Abu Dhabi Company for Onshore Oil Operations (ADCO) during the implementation of Unified Collaboration and Communication across the wide company assets covering the offices in the headquarters till the remote areas such as fields and rigs. The demonstration highlights the pre initiation and preparation activities that occurred in the earlier phases before starting the implementation and how corporate information technology department established its implementation methodologies and strategies that helped later to shape the road before implementing the project. The history of collaboration implementation in ADCO was among the first collaborative working environment in the region back in 2006. Adopting the latest technology back on that time and utilizing the visualization and audio technologies, in addition it was the first to introduce the 3D projection for subsurface modeling in the region that changed the user experience and move it to different levels. While the paper focuses on the whole project stages, it emphasis as well the theory behind the collaboration and communication in any enterprise and argue that companies born collaborative by nature as communications methods and techniques are naturally agreed upon between its employees with no define rules and boundaries. The theory illustrate that the human nature and culture by default embraces the collaboration in its basic means but on the other hand corporate directions, polices and rules might exploit such collaboration and have an effect on it in such way that can result in positive or negative directions. The importance of applying Unified Communication and Collaboration was great step for ADCO as a company toward its operation excellence that enabled ADCO as an organization to better utilizing the existing solutions, accelerating people processes and technologies associated in any given job, putting all that information in one particular place, rational decisions can be made by experts using the correct tools as well as the right information and sharing it in real-time. There is no doubt that the project faced challenges before, during and post implementation, as result lesson learnt was important to be captured to be a later reference to implementation of such similar projects. In addition management of change as well was a crucial milestone of this project while giving proper planning enough time and determining right approach of user adoption will affect how users will be embraces or resisting such change or to be part of the new collaborative experience.
Automation of ADCO Well Delivery Process - A Dream that has Become a Reality
Authors: Zahran Hussein F , Al-Fardan Firas I 
Published: December 2014

Abstract
The process of well planning & well delivery consists of several connected sub-processes and major activities that are carried out across different organizational functions and disciplines; on the other hand demand for energy increases, and ADCO as an organization is seeking new ways to optimize and improve operations – shortening timeframes to production and optimizing cash flow; taking those facts into consideration ADCO decided to take a lead in building an innovative solution entirely in-house gaining from the technical expertise of the different business units within the organization and its CIT division to provide a cutting-edge solution.
Electronic Well Delivery Process (eWDP) provides a standardized method to easily manage and track all pre-drilling/post-drilling activities including tasks, documents, people & rigs.
With the eWDP release, a measurable positive impact has been observed and the mentioned below is a set of day to day savings eWDP is contributing for the overall corporate objectives
Different asset teams were able to smoothly communicate the drilling requirements in a productive manner allowing obtaining the right approvals on time, giving an edge for management to forecast the set strategic objectives and enabling the right decisions to be taken. Planning teams are able to forecast the drilling materials requirements at an early stage through navigating automatically the store inventory and identifying the availability of drilling materials. eWDP provides drilling operation teams with tools to forecast the best rig move route for the allocated rigs "Rig Move Optimization", allowing optimization in terms of both cost and duration optimization. Planners are able to optimize drilling plans according to the performance of the execution of the strategic objectives, which allows for taking the corrective actions on time and avoiding potential planning risks.
As a conclusion the eWDP provides a local knowledgebase for the practices ADCO follows in the well delivery process, setting the basis for optimizing the overall business performance in alignment with set goals.
Sweetening and Sulfur Recovery of Sour Associated Gas and Lean Acid Gas in the Middle East
Authors: Hauwert Peter 
Published: December 2014

Abstract
With increasing numbers of remote fields of a small-to-medium sulfur load (1-100 tpd S) starting to produce in the Middle East, the demand has arisen for sulfur recovery processes that operate safely and reliably at this scale. While several processes have been presented in the last two decades, some doubts exist with operating companies on the reliability, the operational simplicity and flexibility regarding inlet conditions. In this paper, several processes are compared qualitatively for desulfurization of associated gas. Specifically the applicability of the Thiopaq O&G bio-desulfurization process for treatment of associated gas in the Middle East is investigated in more detail.
The Thiopaq O&G process combines sweetening and sulfur recovery of gas streams containing H2S (50 ppmv-100% vol.), and is relatively insensitive to fluctuations in feed flow, pressure and H2S concentration. Because of this robustness, it is ideally suited for treatment of sour associated gas, as the composition and flow vary more than that of typical natural gas or amine tail gas feeding Sulfur Recovery Units (SRU). Besides associated gas, the broad range of suitable H2S concentrations makes it also very interesting for sulfur recovery from lean acid gas streams.
As a large part of the world's sour associated gas is found in the Middle East, the influence of a desert environment on this ambient temperature process using bacteria is further investigated. Plant data are presented that underline the operational stability of the process. Also the simple engineering measures taken to apply this process in a desert environment (hot, arid, limited operators) are presented, along with the economic impact of these measures. Finally, a typical design of a sour associated gas treatment process is shared. In conclusion, the Thiopaq O&G process is a highly suitable solution for desulfurization of sour associated gas sources in (sub)tropical and desert climates.
Role of Integrated Asset Model in Selecting an Optimum Development Scenario and Assessing Uncertainty of a Multilayered Rich Gas Condensate Reservoirs – A Case Study from ADCO Fields, UAE
Authors: El Bahri Sami , Al-Shaarawy Osama , Chouaibi Mohieddine , Torrens Richard , Ghorayeb Kassem 
Published: December 2014

Abstract
For a field development planning (FDP) study of a multilayered, thin, and relatively tight, rich gas condensate reservoir in an Abu Dhabi Company for Onshore Oil Operations (ADCO) field, integrating surface and subsurface elements provided more accurate accounting for the backpressure impact of the production system on the reservoir than is traditionally achievable using standalone reservoir simulation. The backpressure response is a critical factor that must be properly taken into account when modeling multilayered rich gas condensate reservoirs when an early water production is expected.
This gas condensate field is located an environmentally sensitive area, which has dictated a shallow water and onshore strategy to minimize the number of drilling facilities. The development wells will be drilled from several well pads (up to six) located in both shallow water and onshore.
The integrated asset model (IAM) has three components: the reservoir simulation model (built using a compositional finite difference simulator), the well models, and the surface network model (built in a steady-state multiphase flow simulator). The individual models were linked together within a production operations software platform that enables dynamic linking and controlling of the various packages.
Several development scenarios (43) were used to investigate the impact of the following sensitivities on field performance: production phasing, separator sizing, flow assurance, well tubing and flowline sizing, and compression. The IAM was also used to facilitate the economic evaluation for each case. The ultimate objective of the IAM is to select the optimal FDP for multilayered rich gas condensate reservoirs.