bluuebunny/crossref_metadata_2025_split huggingface dataset:
Integrated Reservoir Management and Development Best Practice to Maximize Oil Recovery in a Mature Field
Authors: Al-Amrie Omar , Pearce Adrian , Gunasan Erkan , Madathil Asok 
Published: December 2014

Abstract
Oil demand is increasing globally while new oil developments are getting smaller and more challenging to develop (unconventional oil & gas reservoirs, deep offshore, tight reservoirs, heavy oil, acid gas, shale gas etc). In this context, extending the life of mature, conventional oil fields plays an important role in supporting world oil demand.
Reservoir management and development of these mature fields is challenging and requires innovative solutions given the increasing technical costs as production declines and asset/well integrity costs rise. Technically, a good understanding of reservoir behaviour and production mechanisms leads to implementing appropriate solutions to maximize field life, recovery factor and curb production decline. Commercially, the challenge is to find pragmatic and economically viable solutions.
The field discussed in this paper is a mature carbonate offshore oilfield in the territorial waters of Abu Dhabi operated since 1974. After 40 years of production, the field is still producing economically and currently is producing with an average water cut of more than 90%. This paper presents the continuous evolution of the technologies that have been deployed throughout the years to further valorise resources, in response to the growing maturity and complexity of the field.
Various IOR techniques have been employed in this field ranging from ESP's, gas lift, intelligent completions, multi-lateral wells, splitter wells, dumpflood to selective completions. In addition, various EOR techniques have been used ranging from full field tertiary hydrocarbon gas injection to chemical and enzyme EOR pilots.
Given the aging production facilities, field management is a daily challenge. The complex gas scheme composed of simultaneous gas production, tertiary gas injection, gas lift, gas recompression and gas export requires continuous arbitration between activation gain and tertiary recovery.
Lessons learnt, good and bad, will help maximize future recovery in other less mature fields in the UAE.
New Generation Ultra-High Temperature Synthetic-Based Drilling Fluid; Development and Best Practices for Extreme Conditions and ECD Management
Authors: Marinescu Pavel , Young Steve , Iskander Gamal Ramses 
Published: December 2014

Abstract
In the last years the quest for hydrocarbons findings moved into extreme drilling condition, such as ultra-deep waters, ultra-high temperatures and drilling fluids densities. Adding to these the very narrow density windows (reservoirs with very low differential fracture pressure - pore pressure), both operators and drilling fluids service companies faces increased challenges to deliver the well for production. It is common that for such applications the bottom-hole static temperature is over 180°C/356°F, even reaching temperatures in excess of 250°C/482°F in some fields, acid gases (CO2, H2S) are also present, so the list of challenges is formidable.
In this paper, the authors details the common challenges for such extreme conditions wells and best practices, present a new generation synthetic-based fluid capable to withstand temperatures in excess of 500°F/260°C, as well as a unique hydraulics engineering calculations software which enable real time equivalent-circulation density (ECD) calculations.
The design and development of the mew ultra-high temperature mud system is presented and its components. At the core of the system it is a new amine-free emulsifier, which is stable to temperature above 300°C/572°F. In addition, the authors will present the extensive lab work required to optimize the formulation for high densities and extreme high temperatures, detailing also the critical fluids engineering guidelines for drilling in such harsh conditions.
Using laboratory, field, and computer data, the authors will demonstrate the effectiveness of the new fluid in delivering optimum drilling in extreme HTHP conditions. Also, it is illustrated how the rheology is maintained at minimum level with a micron-size weighting material, and the engineering software used for pre-planning and while drilling to accurately calculate the ECD and maintain it within the required range.
Dewatering Pigging Frequency For Oil & Gas Pipelines Modified Approach
Authors: Grandhe Siva Prasadarao , El Alfy Mahmoud 
Published: December 2014

Abstract
ADCO operates ~165 nos of piggable Oil & Gas pipelines extending over 2500KM. These pipelines transport produced Oil & Gas fluids from RDS, RMS`s to CDS at each interior based Assets and later the treated Oil & Gas is transported to export, distribution terminals with in UAE. The age of these pipelines is in the range 2 to 50 yrs.
The dewatering pigging activity is performed on critical piggable Oil & Gas pipelines at specified regular intervals towards removing the stagnant corrosive water, debris from the bottom of the pipelines, thereby improving the performance of internal corrosion management systems. With the aging of reservoirs associated with implementation of enhanced oil recovery techniques such as water injection, Gas injection etc., the BS&W levels & GOR levels are increasing day by day with the produced crude oil. This has led to high fluid velocity in many operating oil transfer lines.
There is no industry standard and or code of practice available for deciding the de-watering pigging frequency for the pipelines. In view of risks associated with pipeline pigging activities, production deferments associated with pipeline pigging activity with the high flow rate pipelines and the requirement for enhancing the efficiency of internal corrosion mitigation systems, an optimized structured semi-quantitative risk based approach is developed for identifying the optimal pigging frequency for piggable Oil & Gas pipelines based on pipeline throughput, integrity status & operating conditions.
Water Saturation Modeling of Complex Carbonate Reservoir: A Case Study of Challenging Highly Impacted Reservoir by Diagenesis Processes
Authors: Voleti D. K. , Al Mazrouei S. , Al Nuaimi L. Obaid 
Published: December 2014

Abstract
Modeling of water saturation in carbonate reservoirs is a challenging task which becomes more difficult if the reservoir is highly affected by diagenesis processes. This paper addresses a robust water saturation modeling workflow that encompass multiple approaches followed to handle an onshore Abu Dhabi carbonate reservoir that have complex pore network. This covers a holistic reservoir petrophysical evaluation all the way to water saturation modeling for dynamic simulation studies.
The studied reservoir was deposited in high energy shallow, water platform environment prevailing during Early Cretaceous time. It has a large areal extent with low average porosity and moderate to low average permeability.
Considering the impact of porosity exponent (m) and water resistivity (Rw) on the water saturation evaluation, the workflow was adjusted to integrate all available log, core and well test data. By integrating the formation resistivity factor (FRF) at different net confining stress and petrography data, relationship for variable porosity exponent (m) versus porosity was developed.
The salinity variation was observed across the field (east to west) from the well test and Pickett plot. In water saturation estimation, salinity taken from one side of the field (east/west) causes either under or overestimation of water saturation by 18% on the other side of the field which has a Considerable impact on the STOIIP. To address this problem, variable formation water resistivity (Rw) was generated from log data. This was validated using Porous Plate capillary pressure data measured using samples collected from different areas of the field.
The destructive dolomitization at the bottom part of the reservoir resulted in the large transition zone and sporadic occurrence of poor lithofacies poses a great challenge in developing a saturation height function. The current case study also evaluates the best possible saturation height function which can explain the variability of water saturation across the field.
Quantifying HSE Culture – A Leading Indicator of HSE Performance: An Energy Industry Case Study
Authors: Rodrigues C. C. , Simmons R. J. , Atanas J. P. 
Published: December 2014

Abstract
This paper presents the results of an HSE Culture survey administered to employees and managers at an energy company. HSE culture can be defined as the value and priority placed upon HSE by every individual in an organization, and can be seen as the shared values and norms of personnel within a company, their perceptions, feelings, beliefs, and attitudes about the HSE risk to which they are exposed, and their beliefs regarding the necessity and success of HSE control systems. The HSE perception survey is a commonly-used technique for assessing HSE culture. HSE perception surveys provide leading-indicator information on safety performance and can identify areas and activities with the potential to undermine HSE performance. Furthermore, perception surveys can measure effectiveness of HSE systems as described by individuals within an organization, reveal strengths and weaknesses in current systems, and can identify what needs to be done to correct identified deficiencies. The aim of this study was to evaluate HSE culture within the selected company using a technique that is well-documented in the literature. An 8-parameter, 5-element per parameter, Likert scale survey instrument was developed and administered to 108 employees and managers at an energy company. The collected responses were analyzed using Minitab. The results showed that, overall, the company's HSE culture was rated as positive by both employees and managers. In addition, further study of individual parameter groupings revealed that system safety and risk management made the greatest contribution to the positive HSE culture for the company. This was interesting, as it suggests that the average employee has a sense that engineers can play an important role in affecting the overall HSE culture of a company, as they are the usual implementers of system/process safety in the company. This has implications for the importance of creating an HSE-Through-Design culture within the engineering organization at a company.
A New Method of Surface Wave Analysis and OBC Signal Enhancement in Shallow Water Environment of the Arabian Gulf using Time-Frequency-Wavenumber Polarization Analysis
Authors: Zhang Zhao , Sun Yuefeng , Berteussen Karl , Ali Mohammed 
Published: December 2014

Abstract
In the shallow water environment of the Arabian Gulf, a combination of strong lateral seafloor heterogeneities, shallow water depths (~10m), and hard sea bottom results in highly dispersive and aliased surface waves with complex wave-field polarization in all four components of the OBC seismic data. Compared to body waves, surface waves are characterized by low velocity, low frequency and high polarization and their polarization states are time, frequency and mode dependent. Those properties challenge the existing surface waves filtering techniques because they take into account velocity, frequency or polarization only. Consequently, the residual surface wave leads to inaccurate directional analysis and has severe adverse effect on the quality of subsequent seismic data processing algorithms.
Considering the joint relationship among wavenumber, time, frequency and polarization of surface waves, we propose a two- step rotation method to separate the surface waves from the reflected waves and estimate wave polarizations. First, we use a non-stationary FK filter to eliminate the effect of the surface wave from OBC record in the time- frequency-wavenumber (TFK) domain, where we can define the surface wave rejection zone by its low frequency, low velocity and high amplitude characteristics. Second, considering the pattern of particle motion and propagation directions, we estimate wave-field polarization features by extending the traditional single domain polarization analysis into the decomposed TFK domain. Spherically polarization noises (surface waves) can be distinguished from rectilinearly polarized waves (body waves) through covariance matrix calculation for each TFK point. Therefore, the residual surface wave which overlaps with body waves in TFK domain are eliminated based on its polarization characteristic. Analysis on field data shows that this proposed new method is effective in both attenuating the surface waves and providing reliable information on orientation, which are critical for the further processing on the shear wave and converted wave in horizontal components.
Destruction of H2S Contaminants (Benzene, Toluene and Xylenes) by Sulphur Dioxide in Claus Process
Authors: Sinha S. , Raj A. 
Published: December 2014

Abstract
Claus process, consisting of a furnace and catalytic reactors, is used to recover sulfur from H2S found in raw natural gas and gases from refineries. This acid gas is accompanied by contaminants such as benzene, toluene, xylenes (collectively called BTX), other hydrocarbons, NH3, CO2, N2 and sulfur compounds having detrimental effect on catalytic reactors, where BTX form soot particles and sulfur-hydrocarbons, and clog and deactivate the catalysts. This work focuses on BTX oxidation by SO2 as a potential solution that can be carried out in a BTX destruction unit placed between Claus furnace and catalytic units. Density functional theory is used to study the interaction between BTX-radicals and SO2 and the stability of the intermediate species formed during the course of the mechanism. The rates of elementary reactions are evaluated using transition state theory. The pathways leading to the formation of important by-products such as CO, SO, S, CHO were obtained.
Enhanced Gas Recovery by CO2 Sequestration versus Re-fracturing Treatment in Unconventional Shale Gas Reservoirs
Authors: Eshkalak Mohammad O. , Al-Shalabi Emad W. , Sanaei Alireza , Aybar Umut , Sepehrnoori Kamy 
Published: December 2014

Abstract
It is proposed that very low permeability formations are possible candidates for CO2 sequestration. Further, experimental studies have shown that shale formations have huge affinity to adsorb CO2, the order of 5 to 1 compared to the methane. Therefore, potential sequestration of CO2 in shale formations leading to enhanced gas recovery (EGR) will be a promising while challenging target for the oil and gas industry. On the other side, hydraulic re-fracturing treatment of shale gas wells is currently gaining more attention due to the poor performance of shale gas reservoirs after a couple years of production. Hence, investigating and comparing the performance of CO2-EGR with the re-fracturing treatment is essential for the future economic viability of depleted shale gas reservoirs. This paper presents a systematic comparison of the effect of these two processes on improving gas production performance of unconventional reservoirs, which is not well understood and has not been studied thoroughly in the literature.
In this paper, a shale gas field data has been evaluated and incorporated in our simulations for both CO2-EGR and re-fracturing treatment purposes. Numerical simulations are performed using local grid refinement (LGR) in order to accurately model the non-linear pressure drop. Also, a dual-porosity/dual-permeability model is incorporated in the reservoir simulation model. Further, the uncertainties associated with inter-related set of geologic and engineering parameters are evaluated and quantified for re-fracturing treatment through several simulation runs. This comprehensive sensitivity study helps in understanding the key reservoir and fracture properties that affect the production performance and enhanced gas recovery in shale gas reservoirs.
The results showed that re-fracturing treatment outperforms CO2-EGR due to the pronounced effect on cumulative methane gas production. Moreover, the sensitivity analysis showed that the characteristics of reservoir matrix including permeability and porosity are the most influential parameters for re-fracturing treatment. The findings of this study recommend hydraulic re-fracturing of shale reservoirs at first for enhancing gas production followed by CO2 injection at a later time. This work provides field operators with more insight into maximizing gas recovery from unconventional shale gas reservoirs using re-fracturing stimulation, CO2 injection, or a combination of both methods.
Green Hats Induction Program Ensures Safer Workplace
Authors: Ahmed Y. E. , Stander A. , Al Mansouri E. , Turki S. A. 
Published: December 2014

Abstract
Like most drilling contractors worldwide, till a few years ago new recruits joining the company were given a quick induction of few hours in the head office and then dispatched directly to the assigned rigs. Thereafter, rig staff spent time and efforts to train them and get them familiar with company systems. In 2006, the company's management established a specially tailored six week Green Hats Induction Program to get all new recruits familiarized with company rules, regulations, basic safety and drilling procedures - the term "Green Hat" being used to denote employees new to the company who must wear green hats to distinguish them on rigs and require mentoring till they are fully familiar with the assigned rigs The program that was commenced using HSE certified instructors involved discussions between company and OPCOs managements to discuss and review the program syllabus, in addition to the involvement of concerned divisions within the company.
Initially started for junior recruits, within one year, this was expanded to include senior recruits due to the successful outcomes and staff awareness of the first batches.
The Green Hats induction program adds value to the core business of National Drilling Company. It enrolls fresh hires - both new and mid-career hires - and introduces them to the life cycle of wells (drilling and work over) with emphasis on Rig HSE, Drilling Operation and Equipment, team building for onshore and offshore units. All employees undergo mandatory certified courses to allow them to proceed directly after the training to their selected units and to get them familiarized with NDC operating systems and procedures, thereby ensuring personnel safety and a hazard-free work environment in NDC operating zones. By 2009, the Green Hat Program was accredited with the IADC (International Association of Drilling Contractor) Rig Pass – a huge achievement for the company.
Since 2006 a total of 2890 employees have benefited from the Green Hat Program, clocking over 59000 training mandays. The greatest benefit of this program has been the safer workplace and accident mitigation.
This paper shares with the industry the success story and the evolution of this program from its humble beginning to its present success.
Managing Talent Data for Decision Making: Developing ADCO's Succession Management System
Authors: Al Muhairi Ayesha O. , Montes Juan 
Published: December 2014

Abstract
As every organization grows they need to ensure that processes are in place to attract, retain and develop their talent. Succession Planning and Management is a strategic process that focuses on creating a sustainable value chain of high potential talent who have the requisite knowledge and skills to lead and manage new organizational requirements and address business challenges. To manage this process they need to adapt a range of methodologies to select, measure and distinguish between those who are truly high performers with potential.
Abu Dhabi Company for Onshore Oil Operations has implemented the succession planning system from way back in 2006 in preparation for significant challenges in the horizon for which the organization needed to be prepared for:. The challenges included:
Growth in production targets from 1.4 Mbpd to 1.8 Mbpd by 2017 Maturing and more complex fields The need for new technology to be installed to enhance recovery and oil extraction The emerging crew change brought forth by aging manpower and experience dilution and the steep learning curve for newcomers. Reaching the Emiratization target (75%) by 2017,
Implementing a succession plan process within the company was seen as one of the significant intitiatives to support the development of technical capabilities and leadership capacity to address these challenges.
Successful Coring in 8.5-in. Hole Section using Anti-jamming Technology in Southern Iraq
Authors: Khan Asif M. , Onezime Jerome , Mosalem Diaa , Amos Trost , Pointing Mike , Vyas Vishal 
Published: December 2014

Abstract
Field data presented in this paper demonstrate how anti-jamming coring technology was used to improve coring operations at Majnoon field. Majnoon field is located in the southern part of Iraq and is still early in its development phase, with many geological uncertainties. In this geological environment, core samples from the reservoir sections are essential for geologists, geophysicists, and reservoir engineers to better understand and develop a detailed reservoir model.
Previous attempts to obtain core samples in this field experienced poor efficiency, with recurring jamming and limited core recovery, resulting in additional rig time. The lithology of the cored interval consists of interbedded sand, shale, and limestone having occasional traces of pyrite, which has a tendency to damage core bit polycrystalline diamond compact (PDC) cutters.
To overcome these issues, anti-jamming technology featuring a spring loaded-spacer and double-bearing inner assembly was used to core through two compact formations of the well. This technology has already proven its value in other parts of the world; however, this was the first time it was implemented in southern Iraq, achieving its objectives and saving rig time. Seven separate runs were made to cut 151 m of core, all resulting in 100% core recovery at surface with excellent efficiency (98%).
This paper discusses the application of the new coring technology coupled with a premium cutter core head and optimized bottomhole assembly (BHA), which helped mitigate the risks associated with the previous runs and cored into an 8.5-in. section without experiencing any problems.
The Implementation of Model-Based Predictive Emission Monitoring System for Reducing Fuel Consumption and Emissions Output
Authors: Meziou A. Zak 
Published: December 2014

Abstract
Across the globe, the oil and gas industries continue to face stringent emissions monitoring, reporting and reduction goals which require increased reliability and accuracy of the emission monitoring technology and solution. This paper describes the implementation of a patented, model-based, Predictive Emission Monitoring System (PEMS) as an alternative to the traditional hardware-based solutions. PEMS utilizes powerful analytic models with automatic routines for model and real-time sensor validation while accounting for the effects of process and ambient conditions in order to predict emission values with greater reliability and precision. Such model-based systems provide a regulatory certifiable solution with a lower total cost of ownership, and play a strong role in the optimization of burner/boiler efficiency.
The hardware-based approaches may lack the accuracy, timeliness, consistency and security demanded by today's regulations. On the other hand the proposed software-based emission monitoring application takes readings from the processing plant's existing fuel flow, heat value, and mass density monitoring equipment to calculate emissions. It can also provide feedback to plant operators so they can optimize boiler operations for both energy savings and emissions reductions.