bluuebunny/crossref_metadata_2025_split huggingface dataset:
Do Asphaltene Deposition Troubles Happen in Low Asphaltene Content of Crude Oil?
Authors: Takabayashi Katsumo , Maeda Haruo , Miyagawa Yoshihiro , Ikarashi Masayuki , Okabe Hiroshi , Takahashi Satoru , Al-Shehhi Hamad Rashed , Al-Hammadi Hamdan Mohamed 
Published: November 2012

Abstract
An extensive CO2 EOR study was done for one of a super giant oil field reservoir in offshore Abu Dhabi. This study aimed to evaluate the effectiveness of CO2 injection to the target reservoir and to address uncertainties based on laboratory and simulation studies. This paper is focused on the risk analysis of the asphaltene deposition in CO2 injection based on the laboratory data.
In this risk analysis, it is important to distinguish between asphaltene precipitation and deposition. It is believed that precipitation is a necessary but not a sufficient condition for deposition. In some cases, asphaltenes become unstable and form a separate asphaltene rich phase, but they do not deposit. Measurements of asphaltene particle size provide more understanding on the flocculation and deposition mechanisms and allow us to do the risk analysis of asphaltene deposition in CO2 injection. Pressurized oil samples were taken from the target oil reservoir. Laser Light Detection (LLD) and High Pressure Microscope (HPM) systems were utilized to measure asphaltene onset pressure and its aggregation process with injection of CO2. Asphaltene particle size analysis from HPM observations showed the growth of the asphaltene particles. Along with these analyses, CO2 injection core flooding tests were also conducted with this reservoir fluid and this reservoir rock. No symptoms of permeability reduction were observed through the experiments.
The overall conclusion of the study for the target reservoir revealed that the potential risk associated with asphaltene problems during CO2 gas injection was relatively low. In this study, 1) this laboratory study indicated the risk of asphaltene deposition by CO2 injection was relatively low in the target reservoir, 2) combination of the experiments revealed an asphaltene precipitation and deposition mechanism, and 3) this systematic approach was established to assess the asphaltene deposition risk.
Salt Tectonism Offshore U.A.E., a Studied Case
Authors: Al-Suwaidi Ahmad Saqer , Elsaid Mohamed Elhami , Ibrahim Khalil 
Published: November 2012

Abstract
The offshore of the United Arab Emirates (U.A.E.) contains a number of diapiric islands. These islands owe their relief to the diapiric movement of salt which has pierced and deformed the overlying strata. These islands have similar shapes, stratigraphic sequences, aerial distribution of the identified stratigraphic units and general tectonic framework as following: 1. Infracambrian to Cambrian (Hormuz Group) composed of igneous and metamorphic rocks, salt, anhydrite, carbonate and clastics interbeds. 2. Miocene that is composed of sandstone, siltstone, shale, carbonate and evaporite interbeds, and 3. Pliocene to Recent sediments composed of mixed facies of clastics, carbonates and evaporites.
One of the good examples is the pear-shaped Zirku Island with an approximately 5 km long and 2.5 km wide. A zone of very rugged hills with ridges is located in the centre and NNW with an elevated point of 163 meters.
Zirku Island was formed by the movement of Cambrian (Hormuz) salt that was deposited and had moved progressively upward, puncturing through the younger overlying strata to create a dome structure. The surface expressions are composed of evaporites rocks, plus igneous rocks and quartzitic sandstone.
The salt piercement is probably related to the Zagros Orogeny in the Pliocene to early Pleistocene and has brought in materials to the surface from considerable depths. On the Zirku Island the ‘exotic’ materials are represented by a rugged central region of lower Paleozoic contorted sandstones and siltstone of the Hormuz series. In the north east of the central core there is a sequence of steeply dipping lavas out-cropping the eastern flank of the ridge. Bordering the central zone is a gypsiferous breccia or mélange apparently formed around the margin of the Hormuz outcrop during emplacement from depth. The older Hormuz material has been eroded and partly incorporated into calcareous sediments formed along the shore of the ‘structural high’, probably in the late Tertiary period.
Full Field Development Plan Optimization Integrating Subsurface Reservoirs Uncertainties for Green Field Offshore Abu Dhabi, UAE
Authors: Afia Mohamed S. , Al Hossani Khalil , Matarid Tarek , Meziani Said , Al Badi Bader Saif 
Published: November 2012

Abstract
A green field offshore Abu Dhabi is planned to be developed with miscible crestal gas injection and peripheral water injection scheme. Close to 100 slanted and horizontal wells (single in dual/triple Reservoirs) will be drilled from 2 artificial islands targeting four Upper Jurassic carbonate Reservoirs. Risks appear in developing the field due to the uncertainties related to complex faults and fractures network, carbonate reservoirs heterogeneity, Tar Mat, sour fluid production, and high departure wells.
This paper illustrates full field development plan optimization studies that were conducted on a green field. The main objective of those studies was managing the reservoir uncertainties to enhance the full field development plans. 3D seismic, detailed sedimentological study, identified Reservoir rock types, Reservoir fluid characterization (Equations of state) and special core analysis (SCAL) using data collected from limited available wells were comprehensively evaluated and integrated to the input data of a 3D dynamic reservoir model.
In order to achieve the studies objectives, number of parameters were addressed and optimized during assess and select phases of the full field development plan. These parameters are miscible and/or immiscible Gas injection scheme, peripheral Water Injection, Gas Injection timing and balance (standalone field development), and well locations based on structural and sedimentological uncertainties.
Integration of static and dynamic data supported the development plan optimization to address the high uncertainty of the targeted Reservoirs. In addition, several sensitivity studies have been conducted for the reservoir uncertainty parameter ranges to understand their impact on the full field development plan.
Petrophysical Evaluation of a Gas Carbonates Reservoir through Integrated Workflow
Authors: Al Shehhi Noora , El-Hamawi Mohamed , Al Arfi Saif , Desport O. , Padiav P. 
Published: November 2012

Abstract
An appraisal well was drilled to assess the potential of gas bearing carbonate formations. The petrophysical objectives were to determine porosity, permeability, fluid type and saturation. The known presence of anhydrite and the lack of core information in the field to choose the Archie parameters were of concern for the evaluation and had to be addressed by the logging program and the interpretation workflow.
This paper illustrates how the challenge was addressed using neutron elemental spectroscopy to improve lithology and porosity computation, nuclear magnetic resonance and high resolution borehole image to compute a high vertical resolution permeability and finally dielectric measurement to refine Archie parameters.
This paper explains also how the core measurements and test results were used to validate the log measurements and interpretation workflow used.
This case study is a good example of addressing the well objectives using a properly designed logging acquisition and advanced interpretation workflow.
Using Frontline Data to Understand and Manage Cumulative Risk
Authors: Mackay Iain , Lehmann Scott 
Published: November 2012

Abstract
In any organization in hazardous industries there are three primary elements; the plant, the people and the interaction between the people and the plant. The interaction of the people on the plant represents millions of man hours per year for the typical organization and thousands of people every day who routinely intervene in plant operations to do repair and maintenance work. As a result, new hazards are introduced, safety systems are inhibited and parts of the plant are isolated, interfering with standard operating procedures.
The interaction of people with the plant is the biggest area of operational risk and uncertainty. It is the single biggest area of HiPO's, the second leading cause of fatalities and a major contributing factor in almost every process safety incident.
In order to reduce risk and optimize performance in this critical area we can use technology to provide operational assurance and predictive risk capabilities, ensuring people and plant interactions are fully captured into automated and embedded operational processes. Connecting policy to practice in this way ensures frontline workers are carrying out their work according to company standards while capturing and generating valuable data on the type, volume and interaction of work, as well as associated human factors. This provides common risk metrics across operations, enabling organisations to understand the relationship between delivering performance and managing risk.
Ichthys: From Challenge to Reality
Authors: Townsend William 
Published: November 2012

Abstract
INPEX has begun construction of one of the world's largest oil and gas projects following the Final Investment Decision (FID) on the US $34 Billion Ichthys LNG Project in Australia on 13 January 2012. The Ichthys LNG Project is a joint venture between INPEX (Operator) and Total with Tokyo Gas, Osaka Gas, Chubu Electric and Toho Gas.
The Ichthys Field is situated in the Timor Sea approximately 200 kilometers off the Western Australian coast and over 800 kilometers from Darwin. Three exploratory wells drilled in 2000 and 2001 resulted in the discovery of an extremely promising gas and condensate field with resource estimates from two reservoirs totaling approximately 12TCF of gas and 500 million barrels of condensate. Conceptual studies, FEED and ITT followed and development leading to sanctioning of the Ichthys LNG Project by INPEX and Total.
Gas from the Ichthys Gas-Condensate Field in the Browse Basin will undergo preliminary processing offshore to remove water and extract condensate. The gas will then be exported to onshore processing facilities in Darwin via an 889 kilometer subsea Gas Export Pipeline (GEP). Most condensate will be sent to a Floating Production Storage and Offloading (FPSO) vessel for stabilization and storage prior to being shipped to global markets. The Ichthys LNG Project is expected to produce 8.4 million tons of LNG and 1.6 million tons of LPG per annum, along with approximately 100,000 barrels of condensate per day at peak.
Use of Real-Time Surveillance Data for Reservoir Management in a Heterogeneous Carbonate Reservoir
Authors: Konwar Lakshi , Al Zaabi Noura Sultan , Mirza Assif , Mohamed Al Ameri Shaikh Rakkad , Tariq Syed 
Published: November 2012

Abstract
This paper demonstrates the value of collecting and interpreting real-time data for reservoir surveillance. We present three examples of real-time data acquisition and interpretation. The first example shows how formation pressure while drilling (FPWD) data provides permeability quantification for placement of a horizontal lateral. Initial performance of the pilot injector confirmed optimum placement of the well demonstrating value of information (VOI) from real-time data acquisition. In addition, pressure data helped in understanding the pressure distribution along the lateral due to support from a nearby gas injector and also in adjustment of mud parameters for drilling.
The second example highlights the use of downhole fluid analysis (DFA) to confirm gas breakthrough detected earlier by open hole logs, to estimate gas oil ratio of the producer and help selection of fluid sampling point. Integrated analysis of logs, modular formation-dynamics tester (MDT) pressures, DFA results, flow test data and subsequent PVT analysis of oil provided indication of complex gas movement from injector to producer and provided insight on vertical sweep of gas.
The third example demonstrates the use of permanent downhole gauges (PDHG) data for real-time performance monitoring of a maximum reservoir contact (MRC) well. Results of the analysis show clear evidence of voidage balance from nearby MRC injector and underscore the feasibility of field development with water injection in a lower permeability area. Combining the effective well length derived from production logging tool (PLT) data, the example also illustrates pressure /rate deconvolution analysis to determine permeability and skin. Additionally, rate-transient analysis (RTA) is done using rate and high-frequency long-term pressure data to compute permeability, skin and drainage area of the well.
Using Residual Oil Saturation (Sor) to Reduce Uncertainty in Reservoir Modeling - A Case Study
Authors: Al-Housani Habeeba , El Wazeer Fathy , Elsayed Ali Ahmed , Al-Sahn Hani , Xu Siqing 
Published: November 2012

Abstract
Residual hydrocarbon saturation is one of many important inputs necessary to have an accurate dynamic model. It is defined as the remaining hydrocarbon after the reservoir has been fully flooded. An Sor study has been performed in one of the major carbonate fields onshore Abu Dhabi UAE. The hydrocarbon is oil and the flooding fluids are water and lean gas. The residual oil saturation to both water flooding (Sorw) and to gas flooding (Sorg) were calculated.
The determination of Sor is one of the most difficult Petrophysical parameters to be precisely determined in carbonate reservoirs due to their high degree of heterogeneity. In this study we applied practical methods using all available data such as Core data (Sponge core, Liquid trapper & Imbibitions SCAL), Cased hole PNS logs and Open Hole Resistivity logs. Pros and cons of each method will be addressed in the paper. A comprehensive data matrix & analysis was completed; results from different methods were compared to select the appropriate value to be used in the dynamic model.
The impact of the Sor uncertainty on oil recovery was evaluated by performing an uncertainty analysis in the dynamic modelling, for example, an on-going major project which aims to assess the value of developing one of the most complex areas within the field. Uncertainty of both Sor to water and gas were evaluated by assigning ranges based on actual measurements. The study results lead to recommendations for additional field Sor measurements and data acquisition optimisation to reduce remaining uncertainties, which will be presented.
Challenges in Managing Mega Projects in Oil Refining Industry
Authors: Al Yabhouni Al Dhaheri Mohamed O. , Harrision Philip S 
Published: November 2012

Abstract
This paper reviews the challenges faced in the Management of TAKREER's mega Ruwais Refining Expansion Project to achieve high standards for Safety, Quality, Schedule and Costs.

Applications
During the Front End Engineering & Design (FEED), it was recognized that the Project could not be handled as one Contract, for the following reasons:-
Facilities over widespread area. Facilities over widespread area. Numerous process units that are technology intensive. Large utilities requirements Widespread offsites. Huge tankage and product blending requirements. Separate marine facilities requirement. Large financial risk Schedule risk
Seven separate EPC Packages are identified that were defined along logical boundaries and quantum of works. This Strategy presents challenges due to:-
Separate EPC Packages have created numerous interfaces between each Package. Over three thousand interface points have been identified with Responsibilities defined between Packages. There are multiple Process Technology Providers that are interdependent through the processing train requiring efficient and accurate detail design. There are many issues related to logistics such as movement of men and materials. A large multi-national/cultural labour force is engaged comprising 50,000 peak manpower. It is important to ensure that EPC Contractors carry out Engineering, Procurement and Construction as one integrated activity and not each in isolation with different aims and ideals. Otherwise Project will succeed to fail.

Results and Conclusions
The scope of mega Projects needs to be well defined with all entities working together cohesively to achieve success. Manage the Interfaces so that barriers are not formed. Team work is the answer. Manage the Logistics to move men and materials safely and efficiently. Engender Top-down Safety Culture.
Enhancement of Geosciences Workflow through an Efficient, User–Friendly Database Management System
Authors: George Bina , Rudiyono Rudi 
Published: November 2012

Abstract
TOTAL ABK has been operator of the offshore Abu Dhabi field, Abu Al Bukhoosh (ABK) for nearly 40 years. As the field has matured, the field has increased in complexity as has the volume of data, the number of users and the requirements for data handling. With the constant movement of personnel within the affiliate it is absolutely essential that the gold mine of data is kept up-to-date with new users confident that historical data has been reliably stored. When the field came on stream in 1974, slow, unwieldy computer technology had only just begun to emerge in some of the larger companies but technology has advanced dramatically since then and the power of IT is now revolutionizing the way we perceive and use data. The challenge, today, is thus to improve efficiency of storing and accessing data, which is continuously required for interpretative engineering work.
Efficient data management along with a user-friendly interface can help overcome this challenge. The concept of a "GeoInformation" Department was invented by TOTAL to manage the company's data efficiently, so their engineers could focus on field studies. Capturing the data from its birth, checking its quality, classifying it and finally storing it with standard templates is the key to data management. The workflow and the quality control check for each data point and type is different.
Once data is stored in a database, a user-friendly interface (Integrated Reservoir Tool, IRT) with single access point is used to access, visualize and extract the data efficiently. IRT with different charts for various data types enables users to make quick analysis and decisions. Some automated data extractions are also made simple.
By having a master database, the quality and uniqueness of the data is guaranteed. Moreover, the historical data recovery is centralized. If the data is not present in the master database, the user can be confident that the data does not exist. User can access and extract the data by themselves without any support.
The beauty of the system is that it is an IT system built by IT specialists but designed and used by geoscientists. The database is no longer a "black box", it is a living system accessed every minute by geoscientists both onshore and offshore.
Full Integrated Diagenesis and Reservoir Rock-Log Typing: Case Study of Two Complex Carbonate Reservoirs
Authors: Al Mazrooei Suhaila , Matthews Anna , George Bovan , Looser Mirko , Allen Joseph , Soyhan Nurgul , Abbassi Hamid , Mittal Vinod , Al Ali Ibrahem , Hall Jonathan 
Published: November 2012

Abstract
Development of complex carbonate reservoirs requires a thorough evaluation of rock properties, especially when the reservoir has been highly influenced by diagenetic processes. Understanding the distribution of reservoir quality is a prerequisite to successful prediction of reservoir performance. This study focuses on the integration of diagenetic studies with reservoir rock-log typing. The objective was to understand the present day pore space system by evaluating the diagenetic overprint and its control on the studied reservoirs porosity, permeability and capillarity.
In the cored intervals of the studied reservoirs the lithofacies indicate a high energy shallow, water platform environment prevailing during Early Cretaceous time. Both reservoir thicknesses vary between 20 and 30 feet in thickness. Average porosity and permeability are less than 20% and 20 mD, respectively.
Detailed petrographic evaluation, stable isotope analysis, cathodoluminescence and fluid inclusion analysis were employed to develop the diagenetic model. The major controls on reservoir quality and diagenetic feature distribution were integrated and mapped within the sequence stratigraphic framework.
Furthermore, a diagenetic facies scheme was established incorporating core description, petrography, RCA and MICP. The diagenesis evaluation was followed by a reservoir rock typing study to demonstrate the relationship between the identified diagenetic facies and established reservoir rock types using RCA, MICP and log data.
Reservoir rock types were distinguished by their distinct storage and flow capacity characteristics from MICP and RCA. Multivariate statistical techniques were used to classify reservoir intervals into their reservoir rock types from the log data. Correspondence analysis was performed to corroborate relationships between the diagenetic facies and reservoir rock types. This was validated using saturation height functions within/between rock types.
The results of this study will have lasting value to the asset. The geological and reservoir models being developed reveal controls and distribution of reservoir quality and can be updated and optimized with future planned data acquisition.
Challenges Make Championship, First Dual Lateral Well with Slotted / Blank Liner in ADCO: Utilizing Latest Technology to Challenge the Business Plan
Authors: El-Saify Abdel Fattah , Al Menhali Adnan Mohammed , Al Shamsi Juma , Kuyken Chris 
Published: November 2012

Abstract
Dual lateral drilling represents one of the industry's most challenging engineering accomplishments, which will have huge impact on saving days and cost in business plan. Dual lateral is a technique delivering higher production by drilling minimum number of wells as the recovery of oil and gas becomes more complex. Those drilling techniques would broaden our limits to comply with the world's increase in demand while maintaining the high level of Health Safey Enviroment (HSE).
Multi-lateral drilling techniques were successfully enhanced and implemented in one of ADCO's highest risky potential fields. The project was successfully delivered ahead off the planned duration leading to a positive significant impact on saving business plan days and cost. There were numerous challenges in terms of the harsh sour gas environment and successfully achieving the highly complex directional requirements. In addition, the open hole logging data were safely acquired. The well was completed with a 6628 ft slotted liner and blank off bottom liner with External open hole Circulating Packer (ECP) with successful cementing operation.