bluuebunny/crossref_metadata_2025_split huggingface dataset:
Enhancement of Routine Data Acquisition in a Giant Offshore Brownfield by Bridging Gaps Identified Through Comprehensive Data Analysis
Authors: Zhao Wenyang , Al-Neaimi Ahmed Khaleefa , Saif Omar Yousef , Abed Abdalla Abdel 
Published: November 2019

Abstract
Reservoir management is a data driven process with an objective to achieve an optimum ultimate oil recovery. It is fundamental to obtain a proper understanding of well and reservoir performance, which can only be built based on the acquired data. Data acquisition in brownfield has been a significant challenge due to the obsolete control system, accessibility and workflows. Daily well changes is one of the key pieces of data required in routine allocation, well performance analysis, as well as simulation model updates and hence development plans. There are two major types of acquired data in the presented giant offshore brownfield, which are manually measured by operators and automatically recorded data through available SCADA system. A comprehensive data analysis has been conducted based on historical production data and reservoir surveillance data to spot the gaps and identify the opportunities for future improvement.
Gaps in daily well changes data have been observed from both manually and automatically acquired data. It has been summarized into two main categories, which are data inaccurate and data missing. The inaccuracies are mainly from improper use of well change event types, inaccurate timing of data acquisition and malfunctioning of SCADA systems. Missing data includes loss of manual measurement records and insufficient utilization of SCADA data. The paper presents real examples of all these findings and a proposed workflow to enhance the data acquisition process. The concise and explicit workflow is one of the most efficient approach to tackle the hardware and manpower limitations. The importance of daily production events could not be over emphasized. Specific actions to bridge the identified gaps are crucial to achieve a sound reservoir management, maintain the sustainability, and ensure an optimum oil recovery.
Mitigate H2S Spike in 4A Molecular Sieve Gas Dehydration
Authors: Sreenivasan Venkatesh , Alladwar Santosh Govindrao , Noakes Kim 
Published: November 2019

Abstract
Dealing with wet sour natural gas is a global challenge faced in many plants worldwide and dehydration units are to be optimized to reduce the overall project cost. Normally 3A molecular sieve is preferred in sour gas dehydration applications as it does not adsorb H2S. The design illustrated in this paper depicts an innovative method for designing sour gas dehydration units using 4A molecular sieve that can mitigate H2S spike, reduce molecular sieve unit capital cost and operating cost of regeneration system by use of variable adsorption cycle.
The variable adsorption cycle increases water loading in beds by maximizing adsorption time to desorb H2S molecules and thereby mitigate H2S spike during regeneration. This also prolongs mole sieve bed life by reducing the number of bed regeneration cycles as compared to fixed adsorption cycle. This design can be used in gas dehydration units downstream of acid gas removal units.
This paper also proposes to avoid mixing of regeneration gas with main feed gas of mole sieve bed and instead propose to treat the regeneration gas at upstream acid gas removal unit to accommodate the H2S spike.
First Successful Innovative Approach of Pad Drilling Implementation in a Brown Onshore Oil Field in the United Arab Emirates
Authors: Quintero Fernando , Ahmad Hussain Mushtaq , Al Reyami Mazin , Al Nuaimi Mouza Ali , Al Dhanhani Omar Ahmed , Pham Dang Le Khoa , Abdulmohsen Abed Mohammed Al Yafie Mohammed 
Published: November 2019

Abstract
Pad Drilling Concept was developed to increase and sustain the production rate one of the UAE Brownfield Onshore Oilfield (BO) from four different reservoirs. The surface facilities of the field will accommodate total of 80Mbd and technical rate of 96Mbd.
The project scope was redefined in 2016 to enhance the overall project's cost and further study on newly developed reservoir (Reservoir "A"). The project came into execution since January 2018 and so far, 100 plus wells drilled successfully. Therefore, to accommodate the required number of wells based on the company production target ahead of time, the planning stage represented as per 2018-2022 business plan is maintained with first oil in Q1 2020.
The Full Field Development Plan (FFDP) is to deliver a total of 210 wells to sustain the production rate beyond 2024. Thus, the selected scheme for the FFDP which is planned to be artificially lifted is based on water injection and water alternating gas injection (WAG).
The Key aspects of the project are:Partial development of Reservoir "A"Sensitive environmental areaBrownfield development in Simultaneous Operations (SIMOPS) conditions.Directional Drilling trajectory and anticollision constrains.
Critical success factors for this project are:Integrated Project Management Team with dedicated full time resourcesAppointment and selection of competent Engineering contractor to develop the facilities within the target time.Timely approval and implementation of project's milestone.
Thus, the benefits from the project for this Field are:Optimized Field Development Plan;Prevent congestions & access constraints;Standardization of HSE & Operations;Economical Surface Facilities Management.Rig days and cost saving.Sweep Efficiency of the reservoir.Early completion / production of project.
New PDO Improved Well Design 15K Cemented Completion to Successfully Deliver Faster and Cheaper Complex Deep Gas HPHT Wells
Authors: Al Naabi Hashil Nasser , Al Hinai Al Mukhtar , Al Adawi Anwar Said , Al Kiyumi Hassan Ali , Al Aghbari Mohammed Ali , Al Abri Mohammed Thabit , Al Suleimani Ibrahim Hamed , Al Busaidi Naser Mohammed , Al Humaimi Mahmood Ahmed , Youssef Hamada Abdelhameid 
Published: November 2019

Abstract
This paper discusses the continuous improvement in Khulud field, the most challenging field in Sultanate of Oman in terms of high pressure and high temperature. A paper (SPE-188629-MS) was published in 2017 under the title of " Achieving a Step Change in Well Duration and Cost in a HPHT Tight Gas Field" which explained many improvements in different areas including (10k cemented completion and degraded mud, operational optimization and efficiency, slim design). However, in this paper, the focus will be on 15k cemented completion, which was a challenge in that time for both designs (fat and slim). Thus, the new improvement is mainly in well design, which led to significant reduction in well delivery cost and time for 15k wells.
Drilling and completing very tight HPHT deep Gas well can be very challenging. The risk of losing the well is real due to challenges related to liner hanger system failures that have been experienced several times within the field. In addition, stuck pipe risk of cleanout assembly prior to running liner top completion is another serious challenge that had led to abandoning a few wells in the past.
Cemented completion for 15K well is one of the challenges mentioned in the SPE-188629-MS paper in Khulud field. Production casing is not strong enough to handle hot kill load in case completion tubing leaks and as well is not designed for full gas displacement. In addition, many failures were encountered with liner hanger system, which compromises well delivery in some cases. To overcome such challenges and reduce well delivery time and cost, PDO initiated new well designs to cater for 15k cemented completion for both fat and slim applications. Advantages and disadvantages of cemented completion for both designs will be discussed in this paper.
In fat design, production casing was upgraded to higher weight and grade. 7 in casing was eliminated as the new production casing is good enough to handle hot kill load in case tubing leak happens.
In slim design, ECD and high surface pressure are the main concerns. The team managed to simulate, optimize ECD for different scenarios and mitigate high surface pressure. All Risks and associated consequences were captured. A mitigation plan was developed. Future improved design has been evaluated but not approved yet which will drive cost reduction and operational efficiency.
The Application of a Fiberglass Liner in Well Tubing as Cost Effective Material Option in High Velocity Production Wells
Authors: Repetto Carmen , Gorini Simone , Nutricato Giacomo Andrea , Torri Lucia , Cavassi Paolo , Zucchetto Maria Ornella , Guglielmo Carmelo , Gravante Elpidio , McIntosh Neil , Balistrieri Roberto 
Published: November 2019

Abstract
The composite liner is made of a Glassfibre Reinforced Epoxy (GRE) resin, inserted in Carbon Steel tubing and it can be used in both production and water injection wells.
Different laboratory tests performed either by manufacturers and by operators, have been carried out in order to confirm and verify the material characteristics and reliability.
In particular, Eni in 2009 tested GRE in sour environment with CO2 and H2S to investigate the capability and service limits of the resin liner at different temperatures.
According to the positive results of the tests, Eni has firstly applied GRE in 2005 in Tunisia where it was successful in reducing onshore workover costs and extending the life of Carbon Steel tubing in oil producer wells with high CO2 and water cut.
The latest application was in Norway where it has been installed on water injector offshore wells, where, due to high corrosiveness of the injection fluid (raw seawater with antifouling chlorination), the liner was selected as cost effective alternative to high alloyed materials.
More recently, Eni was involved in particularly challenging deepwater development projects with highly productive gas wells in sour and harsh environment.
Typically, these applications require high grade Corrosion Resistant Alloys (CRA) production tubing with an important impact on the completion costs and operative run in hole issues. Following the positive experiences gained in the last 15 years in the application of glassfibre liner, it was evaluated the possibility to deploy the material as a corrosion barrier in well production tubings under more critical conditions.
Eni decided to perform some additional laboratory tests in collaboration with Milan Polytechnic. Direct impact test and straight pipe test were performed in order to characterize the erosion behaviour of GRE composite material, supplied by two different manufacturers, and simulating the case of wells with high erosion rate risk.
The results demonstrated GRE to have a good resistance to the solid particles erosion in comparison to very similar tests on Inconel Nickel Alloy material and confirmed the potential use of GRE as a corrosion resistance material when combined with Carbon Steel tubulars as an alternative to the usual high CRA materials in producer wells.
This paper will present the characteristics of the technology, the laboratory tests performed with their results and the acceptable range of field conditions.
Additionally, the paper will provide Eni field experiences, including feedback, lessons learned and economic evaluations.
Integrated Reservoir Modelling using Spatio-Temporal Unsupervised Learning and Integrated Visualization
Authors: Simha Srungeer , Tummala Pradeep , Kumar Viren , Singhal Manu , Viswanathan Michelle , Kawar Raed , Dijk Harm 
Published: November 2019

Abstract
Probabilistic modelling is one of the most frequently used methods in reservoir simulation to manage uncertainties and assess their impact on reservoir behavior/cumulative production. However, depending on the extent of the uncertainty, 100s of scenarios can be generated leaving engineers unable to meaningfully analyze this data. To remedy this an unsupervised machine learning based workflow was developed to identify unique scenarios which was then paired with an integrated dashboard to enable rapid and deep analysis.
A case study was done using data from a Shell operated gas field in the North Sea. Data was first mined from 480 history matched scenarios using python; out of which 20 unique clusters were identified through K-Means clustering of pressure and saturation changes with time in each gridblock. This meant that the team had to look only at 20 scenarios instead of 480 to understand the effect of different inputs on pressure and saturation response. For enhanced analysis, an integrated visualisation dashboard was created to visualize pressure and saturation changes, production profiles and connect them back to input parameters
The new methodology enabled the team to integrate different aspects of reservoir modelling from static to dynamic to surface constraints on a single dashboard, making it possible to find patterns in large volumes of data which was previously not possible. For example, a cluster was identified which had high water movement; upon inspection of input parameters it was seen that late life recovery was significantly different in this cluster as compared to others. Being able to visualize different properties of multiple scenarios simultaneously at both group and grid level is a very powerful tool that not only generates insights but significantly reduces analysis time and helps in quality checking property modelling and grid behavior.
The developed workflow is quite generic in nature, capable of working with various simulators and can be extended to assessing history match quality in Assisted History Matching (AHM) and multi-scenario modelling. Key parameters impacting different scenarios were identified and the team observed 10x reduction in time and significant reduction in manpower requirements through the new approach
Fully Integrated Modelling of Subsurface, Remote Sensing and Outcrop Geology; Prospect Generation in the Paleozoic of the Ahnet Basin Algeria
Authors: van Dijk Janpieter , Guney Hasan 
Published: November 2019

Abstract
The fully integrated modelling of subsurface seismic and well data with outcropping surface geological data is a challenge in which the application of modern technologies which involves the standardisation of datasets on different scales and from different sources plays a key role. In this paper we present an example of the Paleozoic of the Ahnet Basin in Algeria where a prospect generation exercise was undertaken integrating data from 2d and 3d seismic volumes, logs and core data from previously drilled wells, maps of outcropping geology, and high-resolution remote sensing datasets.
The geology of the area is well known from previous studies on both surface geology and well data, and comprises a Paleozoic series unconformably resting on infra-Cambrian relative basement, and made up of clastic sedimentary series with intercalation of limestone sediments ranging from Cambrian to Devonian Age, which comprise various gas bearing tight reservoirs some of which producing in this part of the Basin. These are present in anticlinal structures of Hercynian Age which are partly eroded and covered by Cretaceous bioclastic limestones. The anticlines show a deformational history reflecting an interference of differently oriented Hercynian transpressional deformation patterns overprinted by later stage, Alpine reactivations. Our integrated geological analyses permitted to propose a new updated view on the geological history of the area. This includes the reconstruction of the structural deformation of the Hercynian anticlines, and the reconstruction of the post-Hercynian geological evolution including structural reactivation, showing tilting and upheaval of the area in Alpine and Recent times.
An extensive interpretation of outcropping geological structures was performed using high resolution satellite images and specific image processing. This was calibrated with available high-quality geological maps and some later additional limited geological surveys. Detailed well log correlations and seismic interpretation 2d and 3d seismic data provided a detailed framework of subsurface structures. The datasets on surface vand subsurface originally coming from different digital sources were integrated in one uniform interpretation environment using best practice standardization which permitted to drive the seismic interpretation and depth modelling, by carefully calibration with outcropping features such as bedding dip, fault trends and fold axis trends. Applying regional velocity modelling this permitted to correctly map the geological structures and prospects in the area, and perform an articulated exercise of Prospective and Contingent Resources estimates.
The application of an integrated geoscientific workflow deploying up-to-date technologies which integrate GIS with a surface-subsurface 3d modelling space shows the validity of new developments of the 4th Industrial Revolution in the planning of E&P Prospect evaluation.
Application of New Generation Transformer Harmonic Filter Hybrid Solution
Authors: Orlowski Thomas , Jasinski Leszek 
Published: November 2019

Abstract
In recent years, Electrical Submersible Pump operators are facing increasing demands to provide more economical ways of producing crude oil at the well site. One of the ways to decrease the cost of production is to reduce the cost of electrical energy used for the ESP system. The limiting of harmonics produced by ESP electrical systems to IEEE-519 recommended levels is widely used, yet greatly misunderstood, as there are a variety of methods and tools that must be made compatible with the application in order to achieve successful mitigation of the harmonics.
Increased horsepower, larger electrical ESP systems, and greater energy consumption require more space at the well site. On offshore installations, that space has always been at a premium. The footprint expansion of this ESP electrical equipment would create unacceptable costs considering the current cost-saving market conditions.
This paper presents an innovative approach to tackle harmonics mitigation. This significantly smaller and cheaper approach delivers the required IEEE-519 THDI in ESP electrical system whilst incorporating new technologies that present characteristics capable of increasing the run life of an ESP electrical system.
A typical ESP electrical system installation has usually contained the following: SDT – Step Down Transformer, HF – Harmonic Filter [or some other means of controlling harmonics], VSD- Variable Speed drive, SWF – Sine Wave Filter, SUT – Step Up Transformer, and ESP Motor. Combining the Step Down Transformer with the Harmonic Filter and designing it as a one-piece unit, cooled in oil, creates a smaller and therefore more cost-effective device, that achieves more desirable harmonics characteristics. Including not only efficient cooling, but the use of parasitic inductances of transformer windings as a useful component of the integrated harmonic filter gives an advantage on the technical market. This paper provides further discussion and details on this concept's advantages as a solution to reducing operating costs.
Competency Assessment of HSE Critical Positions
Authors: Al Muhairi Mohammed , Kruger Michael 
Published: November 2019

Abstract
This paper presents Borouge experience in terms of The Competency assessment of critical positions program which has been developed based on best available practice and it will set Borouge competency strategy for Certification and assessment to uplift the performance and excel in HSE and Process Safety programs.

Statement of Theory and Definitions
Borouge strives to be recognized as a leader for delivering the "Best in Class" HSE and Asset Integrity performance. Due to that we have come up some initiatives which is designed to enhance the HSE performance to prevent incidents.
A Benchmarking study has been conducting to have overall look on how to improve Borouge Education and training system by first analyzing our own process, then finding better process among other comparable Processes.
Objective: ✓Identify opportunities to enhance quality, eliminate duplication, and streamline processes✓Collect baseline data✓Clarify desired outcomes
The benchmarking is encompassing the below areas the HSE training and education: HSE training matrixTraining cycleTraining authorization and certificationPerformance measurement / indicatorNon conformity, corrective action and preventive actionRecord keepingthe competence requirements levelOutlines the training priorities;Review/AuditE- learning system
SmartWater Synergy with Surfactant Chemicals: An Electro-Kinetic Study
Authors: Alghamdi Amani , Ayirala Subhash , Alotaibi Mohammed , Alyousef Ali 
Published: November 2019

Abstract
SmartWater flooding through the injection of optimized chemistry water has lately become an attractive proposition for enhanced oil recovery in carbonate reservoirs. The wettability alteration towards water-wet conditions caused by favorable surface charge alteration is identified as the main mechanism responsible for oil recovery.
In this experimental investigation, the impact of SmartWater/surfactant synergy on wettability alteration was thoroughly studied by measuring zeta-potentials at calcite/brine and crude oil/brine interfaces using electrophoresis technique. Different types of surfactants are considered including: anionic, amphoteric and non-ionic. Four different water recipes representing SmartWater (10-times reduced salinity) were chosen at a fixed lower salinity as well as the high salinity water (HSW).
The results showed that both anionic surfactants increased the magnitude of the negative zeta-potentials at the interfaces by almost same order of magnitude. The negative zeta-potentials of calcite and crude oil were increased the most with anionic surfactants in NaCl brine. SmartWater showed relatively higher negative zeta-potentials for calcite when compared to Na2SO4 brine and HSW in the presence of anionic surfactant. These results indicate that both NaCl brine and SmartWater can synergistically combine with anionic surfactants for effective wettability alteration in carbonates. Amphoteric surfactant showed a negligible impact on electrical double layer (EDL) expansion and consequently the wettability alteration. The nonionic surfactant induced electrostatic repulsion forces at both calcite/brine and crude oil/brine interfaces in high salinity seawater and as a result it can be considered as the best chemical formulation to reduce interfacial tension and cause wettability alteration in conventional chemical flooding processes. The negligible impact of adding surfactant chemicals on the measured di-electric constant of different brines confirmed the robustness of zeta-potential values reported in this study.
This work for the first time evaluated the synergistic effects of different brines including the SmartWater with surfactant chemicals by measuring zeta-potentials at calcite/brine and oil/brine interfaces. The optimally suited water recipes were identified to synergistically combine with these chemicals to enhance wettability alteration in carbonates. The new knowledge gained from this electro-kientic study will provide practical guidance on how to design efficient chemical flooding processes for enhanced oil recovery in carbonate reservoirs.