bluuebunny/crossref_metadata_2025_split huggingface dataset:
Building ADNOC's Pillars for Process Standardization and Best Practices through an Integrated Reservoir Management Framework
Authors: Al Marzouqi Mohamed A. , Bahamaish Jamal , Al Jenaibi Haitham , Al Hammadi Hamdan , Saputelli Luigi 
Published: November 2016

Abstract
UAE has one of the largest portfolios of reservoir development projects across the world. In managing such projects, ADNOC and its operating assets make multiple decisions to optimize production and recovery factor, by selecting the most adequate exploitation plan including among other, reservoir drainage architecture, production allowables and injection distribution. Reservoir management involves the monitoring, analysis and decision making to optimize business performance results and indicators.
ADNOC has envioned strategic goals of reaching sustainable production targets while ascertaining quality assurance through consistency and standardization and by applying best practices. To achieve these strategic goals, ADNOC also identified the following needs, namely: (1) protect the intellectual capital of the workforce (2) train and deploy the growing young workforce faster and consistently, (3) generate the blueprint for consistent workflow execution and (4) provide the platform for expert knowledge sharing and best practices. To achieve these objectives, ADNOC has embraced a framework named Integrated Reservoir Management (IRM) as one of the key management best practices.
IRM is a collection of building blocks, processes, and workflows from surveillance strategy to opportunity generation and execution monitoring. The framework also delineates a set of measurements that allows monitoring of reservoir performance management in the operating assets. It also provides a firm basis for connecting the company strategy with those cross-disciplinary processes and workflows in its day-to-day operations. World-class reservoir management processes include the optimum planning and utilization of reservoir surveillance activities, proper data and information integration to reveal reservoir opportunities, proactive decision making and continuous monitoring of performance.
In this paper, we discuss the experiences in implementing IRM across ADNOC operating assets during the previous two (2) years. The project started identifying current (or as-is) processes used in the operating companies (OPCOs) and across International Oil Companies (IOCs). Based on the analysis of multiple processes in OPCO, a framework of 6 blocks, 18 processes and 29 workflows was developed.
As a result of implementation, IRM framework has allowed sharing standard reservoir management workflows with the added benefits of (a) shortening learning curves to new employees, and hence reducing the total cycle time, resulting in increased productivity, (b) measuring KPI's that cultivate proper behaviors to integrate the right multi-disciplinary efforts in delivering consistent results and (c) fostering a new culture that continuously challenge status quo with consistency.
Application of Ball-Drop Technology to Improve Efficiency and Stimulation of Limited Entry Completion Systems
Authors: Oberhofer Rob 
Published: November 2016

Abstract
Ball-drop or ball-activated completion systems for multistage hydraulic fracturing are designed to reduce stimulation time and improve efficiency by being pumped in one continuous operation. Actuation balls are used in these systems to activate sliding sleeves and internally isolate the production liner into individually isolated stages. While this technology is traditionally associated with single point entry stimulation (one ball per sleeve), advancements in ball-drop technology have led to the development of a system that uses one ball to activate multiple sleeves, combining the efficiency of ball-drop completions with the placement accuracy of limited entry stimulation in cemented liner completions.
Limited entry ball-activated completion technology has evolved over time. Each iteration has been designed with fewer components to further improve the operational efficiency of having one ball activate multiple sleeves in a treatment zone. The latest advancement in this technology has seen a 40% reduction in the number of components, which in turn reduces operational risk. While limited entry ball-drop completion systems have been run for over a decade in openhole applications, the newest version was specially designed to run in a cemented liner application.
The latest version of limited entry ball-activated completion systems is designed to stimulate a high number of entry points in one treatment more effectively, reduce overdisplacement, reduce completion time, remove risk of wireline and coiled tubing runs, eliminate the need to millout the system prior to flowback, and solve entry point erosion concerns. Each port or sleeve is designed to have its own back pressure or limited entry effect (equivalent perforation pressure), which is customizable for each application. By using a non-erodible material in each sleeve the limited entry effect is designed to be consistent throughout the entire stimulation. This is a significant improvement over existing limited entry tools and plug-and-perf completion designs and will lead to more effective distribution throughout the entire stimulation.
In each field trial to date using the new limited entry ball-drop completion technology, all the sleeves have opened and stimulation treatments have been delivered as designed. In the cemented liner applications, the limited entry ball-activated sleeve system allowed stage to stage transitions without shutting down pumping operations.
Limited entry ball-drop completion systems provide instant time and operational improvements to traditional cemented liner completion methods. These time and cost improvements can significantly reduce total well costs, which is especially important for operators in low price commodity environments.
Oil and Gas Co-Development of a Giant Offshore Carbonate Reservoir with Gas Cap: Feasibility Study and Expectations
Authors: Ben Sadok AbdelAziz , Koeck Charles-Henri , Abudaqa Anas 
Published: November 2016

Abstract
Development of Giant carbonate reservoir considerable cap gas and condensate reserves along with oil rim is now being considered as one of the on-hand options to overcome shortage of gas in the long term and to add value to the company assets. This paper presents an overview of the study that was initiated to assess the feasibility of the simultaneous development of gas and oil and to evaluate its impact on the existing oil long term development plan.
A compositional simulation study has been conducted by adding the co-development of the gas cap on top of the current Long Term Oil development plan. This development includes water injection at the original gas oil contact level to isolate the gas cap and to enable to develop gas cap independently from the oil rim. In this scenario, drilling of producers in the gas cap is considered and condensate is produced to the dedicated production system. Several prediction scenarios have been investigated to set up a development plan of gas: Blow down or natural depletion,Produced gas recycling,Lean gas recycling.
The best scenario has then been selected for further optimisation. (On gas injection recycling ratio, project start-up timing, gas production target, and water injection).
After analysing the results, it was found that the blow down of the gas cap provides a good recovery of gas and condensates but has a negative impact on oil reserves.
Gas recycling option proves interesting as it maintains pressure both for condensate (hence preventing drop-out) and for oil; therefore impact on Black-Oil recovery becomes minor.
Oil recovery is higher with late starting time of the co-development or with high recycling ratio. Oil Recovery Factor depends mainly on the pressure maintenance of the reservoir. However excessive gas injection has a negative effect due to breakthrough of the gas into the oil producers which have GOR limit constraints.
Co-development simulation study of the gas cap along with oil, through an inner ring of water injection at gas oil contact shows that the co-development is not only feasible but it will also bring significant value to the company future business plan. Gas cap being semi-isolated from the oil rim, the impact on the oil development plan is minimized.
Co-development proves appealing to the different owners of the field since it brings more gas and LPG that is foreseen as valuable source of enriched gas for later EOR or WAG schemes
Modelling Shale Gas Flow Using the Idea of Apparent Dynamic Permeability
Authors: Farid Syed Munib , Killiugh John E. 
Published: November 2016

Abstract
The basic idea behind this research is to propose a work flow to model gas flow in numerical simulators, which would take into consideration all the complexities of the multiple porosity systems that exist in shale matrix and the different dynamics of flow involved within them. The concept of a multi porosity system that is composed of the organic part (kerogen), inorganic matter and natural and hydraulic fractures is used here. Kerogen is very different from other shale components because of its highly porous nature, capability to adsorb gas and abundance of nano-pores on its surface.
Some theories had been forwarded for the physics involved with gas flow in shale on a micro scale level. However, when working with reservoir scale models, the details as described for porosity systems in micro scale models is lost. To overcome this problem, the idea of dynamic apparent permeability, which is a function of matrix pressure, is introduced in this work. It helps in up-scaling the particulars of the micro scale model to a reservoir one and aids in modelling Darcy flow, Fickian diffusion and transition flow in between the matrix and fractures.
Our assumptions are validated by working with the case of a multi-stage hydraulically fractured horizontal gas well producing from the Barnett shale formation. Exisiting simulation model for this well doesn't take into consideration the relevant flow phenomenon and is used as a base case. History matching after integrating diffusion and desorption, with 7 years of production data, into model reveals that considering these additional processes impacts the assumed SRV region - affecting its volume as well as its properties. This is a critical factor in optimizing completion design, to lower down the well cost for same or even greater production.
We summarize our findings from production forecasts that matrix contribution towards production is under estimated when relevant assumptions for shale are not modelled. This signifies the importance of better understating the transport phenomenon occurring in shale, which would enable us to have a greater insight to scrutinize production data and later to predict changes in production as completion methods are changed. Similarly, this can play a vital role in well spacing for effective field development. This means that a multi stage high density fracturing job might not optimize the well in terms of its value. Decreasing our expenditure on well completions, such that their design results in lower production rates at the initial time period along with lower decline rates, would enable us to produce these wells longer for the same recovery. This would enable us to push the production in future where oil and gas prices might be better.
Advanced Comprehensive Logging While Drilling Dataset for the Evaluation of Low Resistivity Pay Acquired in a Complex Geometry Well of the Nam Con Son Basin of Vietnam
Authors: Das S. , Orr M. , Nguyen V. H. , Diaz E. , Dung L. C. , Hyok J. J. 
Published: November 2016

Abstract
Multi-component resistivity and borehole image logs are commonly used for evaluating low-resistivity laminated sand-shale reservoirs. Stoneley permeability may also be added to help with testing and completion decisions. However, acquiring a comprehensive wireline dataset in a complex J-shape well is extremely challenging. This case study, from the Nam Con Son basin of Vietnam, describes a workflow to effectively use a dataset acquired while drilling to identify and evaluate these low- resistivity reservoirs.
A complete suite of logs, comprising gamma-ray-density-neutron-resistivity-acoustic-resistivity image, was acquired while drilling. The propagation resistivity was processed to obtain horizontal (Rh) and vertical (Rv) resistivities. Laminated Sand Shale Analysis (LSSA), using these inputs, was used to determine the hydrocarbon saturation over the thin beds, and to calculate net pay. A high-definition image log was used to identify the laminated section, and net sand was calculated from this using a threshold technique. The result was compared with that from the Thomas-Stieber method, which also provided shale distribution. Acoustic permeability was also derived using the attenuation of Stoneley wave amplitude.
The conventional resistivity of the thin-bed reservoirs in this basin is generally lower because of the presence of conductive shale layers. Consequently, the conventional formation evaluation approach using these resistivity values resulted in high-water saturation and a small net pay, which did not provide enough justification for a detailed testing and completion plan. The propagation resistivity data was therefore processed using an array inversion technique to provide vertical resistivity (Rv) which is less affected by the laminated shale (Meyer 1998). A high anisotropy (Rv/Rh) was observed against the hydrocarbon-bearing laminated intervals. Using this elevated resistivity in the LSSA method resulted in 52% of additional net pay. The laminar sand volume from the borehole image provided a similar result to that of the Thomas–Steiber and tensor methods, boosting the confidence of the calculation. Permeability calculated from the Stoneley wave, and additional net pay from LSSA, provided adequate information to develop the testing plan which was later pursued. The high-definition image log helped to select the best possible sand layers for testing and sampling.
A comprehensive dataset is required for thorough evaluation of thin-bed, low-resistivity reservoirs, but sometimes the complex well geometry hinders the acquisition process. This case study shows that the suitable data set can be acquired while drilling, and using the resistivity anisotropy along with acoustic permeability and image log can provide detailed information for effective evaluation of these formations.
Characterization and Quantification of the CO2 Sequestration Potential of a Carbonate Aquifer in Falaha Syncline, Onshore Abu Dhabi
Authors: Temitope Ajayi , Gomes Jorge S. , Al Kobaisi Mohammed , Hu Jialiang 
Published: November 2016

Abstract
The capacity for the storage of carbon dioxide in saline aquifers remains enormous. Of all geological storage media, it provides the best storage capacity. In this study, the potential of the Shuaiba Formation, in the Falaha syncline, for geologic sequestration is assessed. A regional geo-model was built using seismic and well data (logs, cores) from the Falaha Syncline and nearby fields. The model was built to honor the heterogeneity and sequence stratigraphy of the Shuaiba carbonate platform using a five-order hierarchical conceptual model of the Shuaiba formation that merged sequence architecture and reservoir architecture together. This was achieved by honoring lithofacies, facies association packages and rock types in their corresponding depositional settings in the sequence framework. Dynamic simulations were then conducted on an upscaled geological model using a compositional reservoir simulator to determine its storage and flow capacity, plume migration pathways and to understand the physics of the fluid flow in the aquifer. Simulations are made to be conservative thus accounting for structural/stratigraphic, solubility (dissolution in resident brine) and residual trapping without accounting for the slower mineral trapping process. Detailed sensitivity studies were conducted during the simulations to understand the effect of well parameters, rock and fluid properties amongst others on the storage capacity in the aquifer. Simulation results indicate that significant volumes could be stored in the aquifer and could take a significant amount of time before the injected gas reaches the surrounding hydrocarbon producing fields. This study provides the first full field approach to characterize and to quantify the suitability of the identified aquifer for long term storage of carbon dioxide in the subsurface of UAE.
Bench-Marking Different Risk Based Inspection RBI Approaches for Inspection Costs Optimization
Authors: Giridhar Y. V. , Manuel J. C. , Al Abri A. M. 
Published: November 2016

Abstract
GASCO has Risk Based Inspection methodology implemented for optimized inspections. The present methodology is based on semi-quantitative approach to calculate Criticality ranking and mitigate risk with the aim to prioritizing inspections. Also to move away from time based inspection to risk based Inspections to minimize risks ALARP (As Low As Reasonably Practical) level.
With improvements in RBI methodologies and better understanding type and rate of damaged mechanisms, inspection intervals become more dependent on the risk and equipment condition.
Following the start in May 1993 of the RBI JIP (Joint Industry Project) managed by API and sponsored by major refining and petrochemical members such as Amoco, BP, Chevron, Conoco, DOW, Exxon, Mobil, Saudi Aramco, Shell, Texaco, a decision was taken by GASCO management to initiate the implementation of its own Risk Based Inspection program.
GASCO RBI pilot exercise was successfully performed in October 1998 at the Bab Plant, in the very early days when this novel concept was just giving its first steps in the Oil & Gas industry worldwide, for refreshing the conventional time-based inspection planning process.
It all started with a relatively simplistic qualitative model developed by GASCO shareholder Shell, which, due to its successful implementation across the industry, rapidly evolved to a more complex but also more technically consistent semi-qualitative model, which was supported by a proprietary database management software branded S-RBI.
Managing the Oil and Gas Talent Equation: Location, Skill and Commitment
Authors: Speers A. , Henchy A. 
Published: November 2016

Abstract
‘People provide the only sustained competitive advantage in the knowledge economy. How can HR and line managers respond to cost cutting calls whilst protecting their company's edge?’
The downturn in the global oil price which began in mid 2014 has had a significant impact on talent acquisition by companies across the oil and gas industry – operators, service companies and others.
In this paper, we will explore how the oil and gas industry – upstream, midstream and downstream - is currently sourcing talent in the Middle East and North Africa (MENA) region, employee sentiment under the current oil price context, how the recruitment sector has adapted during the downturn to meet changing client needs, the talent need in post-sanctions Iran and the main challenges and opportunities – and solutions – facing HR managers seeking to maintain a competitive edge.
The paper will cover the following key themes:Candidate sentiment in MENA in the face of the oil price downturn. How is your most important resource feeling right now and why?Expatriates vs. local content – squaring operational needs with regulatory requirements. Where are expats coming to MENA from? Which local candidates are in good supply and where are the shortages?New markets that offer International Oil Companies (IOCs) opportunities during the downturn such as Iran – the talent need post-sanctionsThe recruitment sector response – increasing specialisationThe key issues and opportunities facing people managers in companies like yours
Standardizing Reservoir Management Best Practices: Lessons Learned from an Innovative Approach in KOC
Authors: Capello M. A. , Dhote P. , Al-Shammari H. S. , Al-Maraghi E. 
Published: November 2016

Abstract
Sound reservoir management practice aims to maximize economic recovery while smartly reducing capital investments and operational costs, optimizing the utilization of technology and talent. Nevertheless, such a conceptual approach, seemingly linear and focused, is challenging in large corporations, for the numerous reservoirs that are produced at different stages of maturity, by a variety of teams.
This is the case of Kuwait Oil Company, the main oil operator of the upstream sector in the State of Kuwait. After more than 67 years of commercial oil production, the company has evolved into a large and complex organization composed by assets and support groups. Incrementally, the need of standard practices of Reservoir Management (RM) is evident, to maximize the optimization efforts at corporate scale.
As an unprecedented initiative, Kuwait Oil Company (KOC) engaged in a journey of standardization of its RM practices, to manage with top standards its more than 142 oil and gas fields on the inland territory of Kuwait. The initiative comprises a two-fold effort: A formal project led by KOC's RM Team, to identify and assess the status of RM Practices in KOC;A Steering Committee of executive level, charged with the implementation of standards policies, guidelines, and workflows for RM.
All Assets in KOC are already benefitting from this approach, as the initial results from the assessment of the current status of Reservoir Management Practices, have established the good practices, as well as the tools and techniques to be massified. At the same time, the identification of existing gaps in Reservoir Management Practices was completed, establishing a clear plan to minimize them. The acceleration of the uplifting of KOC's Reservoir Management (RM) processes, will need a sound governance model for the implementation of the RM policies, grounded on the findings established and customized to the corporate organization and goals of KOC. The achievement of short- and mid-term goals has started, with the PIP (Process Implementation Projects), aimed to enable important improvements of RM in all oil and gas Assets of KOC.