bluuebunny/crossref_metadata_2025_split huggingface dataset:
Maximizing Hydrocarbon Recovery and Water Injection Support through Pattern Reviews Between Injector Producer Pairs in a Large, Complex, and Faulted Brown Field in SE Asia
Authors: Ali Arfan , Gupta Manish K. , Salleh Reza , Bong Charlene 
Published: November 2020

Abstract
Large, complex and faulted structures often pose substantial challenges in maximizing hydrocarbon recovery. This is largely due to limited understanding of field wide connectivity of reservoir sands, across fault communication, and uncertainty in reservoir fluid contacts due to a fewer well penetrations in early life of the field. In addition, secondary recovery through water injection support brings further complexities in such fields, particularly in stacked reservoirs with multiple sands completed across individual production zones.
The work presented in this paper has utilized ‘pattern reviews’ technique in a brown field containing over 500 well penetrations in South East Asia. Pattern reviews have made use of reservoir pressure data, fault maps, sand/shale correlations, salinity variations between formation and Sea water, and injection and production data by carving out specific sections of the field containing injector-producer pairs. The integrated data and analyses have helped establishing connections, or otherwise, between injector-producer pairs across various parts of the field. Time lapse Production Logging (PLT) campaigns were executed to provide additional supporting evidence on flushing of certain reservoir sands in producer wells and preferential injection zones in injector wells.
Systematic selection of patterns containing injector-producer pairs across the field has provided a substantial support in our static and dynamic modelling work to establish reservoir/fault connectivity within fault blocks and across the field. This has subsequently helped in history matching production data as well as identifying infill opportunities for bypassed oil. The present work has also helped in optimizing water flood and choosing certain injectors/zones to open/close for pressure support.
An understanding on the connectivity between injector-producer pairs has also helped in identifying areas with low recovery and poor sweep. This has paved the way in initiating a pilot project for Polymer injection in this field to help understand incremental recovery in addition to water flood. A successful outcome would initiate field wide polymer injection with a potential of 10's of mmboe incremental recovery from the field.
For the first time in field history, pattern reviews have been extensively used as a tool to understand reservoir connectivity and dynamic fluid movements across the field. An additional attempt has been made to use ant track maps to help identify potential baffles and sub-seismic faults. An integrated effort between the various data and disciplines have provided fresh insights into the reservoirs and which would have otherwise been difficult in heterolythic nature stacked reservoirs.
Brownfield Projects Cost & Schedule Optimization
Authors: Mahmood Syed Faisal 
Published: November 2020

Abstract
The brownfield projects deal with existing facilities/assets to upgrade or modify. These projects can be minor (e.g., change a few cable trays) to major (e.g., remove an old gas turbine). These projects are smaller in Capex spending compared to new greenfield projects, and sensitive to completion schedules, because of the facility's operational/production state. Normally some of the work is performed during shutdown of the facility, so there is economic pressure to resume operations as soon possible.
Eighty percent of these projects are schedule-driven, and cost is relatively high if benchmarked with green field projects, which are usually cost-driven projects. There is a need to plan and execute these projects to optimize the cost and schedule, to achieve company's financial goals and production targets simultaneously. These strategies may vary from project to project, and there are many common actions that can be applied to all brownfield projects.
It is a challenge for the project management team (PMT) to execute a brownfield project within the planned budget and schedule, due to uncertainties and constraints. In this paper we will discuss the risks and challenges faced by brownfield PMTs, and how to mitigate risks with planning and execution strategy at different stages of the project life cycle: i.e., concept selection, FEED, detail engineering, project proposal, contract award, execute construction, and commissioning of the facility.
Reduce the Gap Between Planning and Operation : More Reliable Planning by Predicting Downtime
Authors: Jain Piyush , Ouldzmirli Oussama 
Published: November 2020

Abstract

Typical Planning Process
There is different level of planning:
Operation planning is one of the key activities which planners do, it plays a crucial role in overall profitability as planner tried to make most profitable production plan considering various internal and external factors.
External factors can be for feedstock availability and pricing, freight cost, product specs & demands whereas internal factors are unit's availability, operational conditions, blending etc.
SWCTT Data Simulation and Sensitivity Analysis of Measured Residual Oil Saturation
Authors: Felix Servin Jesus Manuel , Shi Nan , Abdel-Fattah Amr 
Published: November 2020

AbstractSingle-well chemical tracer tests (SWCTT) have received burgeoning interest as in-situ methods to measure the remaining oil saturation (S_or). The test not only involves field operations and lab measurements, but also relies on curve fitting of the data acquired from these procedures. Despite various types of errors and uncertainties arising in SWCTT, their effects on data analysis, and in turn the accuracy of S_or measurements, remain unclear. Here, we present a robust SWCTT simulator and use it to perform sensitivity analysis of different parameters over a wide range of reservoir and tracer properties. We find that accurate determination of tracers’ partition coefficients is crucial for estimating S_or, whereas errors in concentration measurements or pore volume characterization have less dramatic effects. More importantly, we demonstrate that matching the SWCTT data is only a necessary condition for the accurate estimation of S_or. In fact, a good data fitting without correct values of parameters such as partition coefficient could yield substantially deviated values of S_or. This sensitivity analysis and the "what-if" capability of our simulator provide in-depth understanding for the design and optimization of SWCTT.
Resolution of Repeatable Bearing Failure of a Gas Re–Circulation Fan
Authors: Ashour Mohammed , Shalabi Mustafa 
Published: November 2020

Abstract
A double suction centrifugal fan with rated power 1120 KW driven by variable speed motor using VFD (variable frequency drive) through flexible coupling (shim pack), fan rolling element bearings vibration is monitored by two seismic vibration sensors (one per bearing) connected to the control room. the fan is one of two gas re-circulation fans of water tube boiler generating steam to drive 650 MW power turbine. on 1st of July 2019 after power plant steam turbine major overhaul, fans started with acceptable vibration levels. Within August to September 2019 the fan bearings showed vibration and temperature increase higher than acceptable limits. Customer inspected both fan bearings and replaced the damaged inboard bearing. After one month of normal operation, the same fan inboard bearing failure occurred with the same characteristics based on the previous history, this plan was implemented: Fan bearings’ housings clearances measuring.Old (failed) bearings visual inspection.Fan inboard bearing replacement.Modal impact test to measure the fan natural frequencies.Startup. vibration data collection and analysis.
It was observed that, fan inboard bearing radial clearance between bearing and housing was 0.22 mm exceeding the maximum allowable limit 0.01 mm. (clearances adjusted as per manufacturer limits) as the fan inboard bearing is double row type, however the both failed bearings showed the same failure pattern on the closest row to the motor mean while the other row was clear. after fan inboard bearing replacement and machine startup, vibration data collected using online vibration analyzer and voltmeters installed on both fan bearings and motor inboard bearing, fan bearings velocity spectrum showed high vibration component at 141 Hz which is close to the bearing outer race fault frequency, and doesn't coincide with any of the fan natural frequencies. motor inboard bearing horizontal sensor showed severe fluctuations and Ski-slope in the spectrum. visual inspection showed damaged ground brush, and after its replacement, all vibration levels decreased, and the 141 Hz component decreased. based on previous observations it was concluded that, as a result of damaged ground brush, ESD (electrostatic discharge) generated and was responsible for fan inboard bearing housing clearances increase overtime, which led to repeatable bearing failures.
this case study is focused on how the root cause analysis performed to avoid the repeatable bearing failure, and the importance of preventive maintenance activities to avoid unplanned failure. also, how the ESD problem was detected through steady state vibration data and applying the appropriate maintenance plan.
Risk Based Maintenance Management System Achieving Operational Excellence
Authors: Abuelenin Marwan Hassan 
Published: November 2020

Abstract
The aim of this abstract is to focus on the Maintenance Management System (MMS) that was implemented at ADNOC LNG to accomplish operation excellence, effective decision-making regarding maintenance activities, and utilization of the Risk Management Process to assure asset integrity and major production revenues.
Risk-based MMS is a continuous improvement (CI) system to proactively prevent failures through the early identifications of risks, failure modes, failure criticality, and risk mitigation by utilizing cost effective predictive maintenance tasks and routines. Risk-based MMS effectively provides support for high critical decisions to assure asset integrity, minimize plant trips, avoid unnecessary forced shutdowns, and guarantee safe operations.
Asset Integrity Management (AIM) is important in the oil and gas business because it ensures reliable assets, performance, efficiency, cost effectiveness, sustainable production revenues, and achieve business objectives and operational excellence. Maintenance, Operations and Engineering are the key partners and custodians to assure asset integrity in compliance with HSE. The very close interface between the three result in high levels of asset reliability and availability.
In 2016 ADNOC LNG's Maintenance Division deployed the Maintenance Management System (MMS) driven by the Risk Based Reliability Approach. The objective was to perform consistent maintenance activities and asset integrity assurance by identifying risks and mitigations to reduce the risks in early stages to As Low As Reasonably Practical (ALARP).
The MMS Policy and Strategy was developed on the foundation of the risk-based approach in line with ADNOC LNG's corporate objectives, ADNOC's code of practice, and internationally accepted best practices.
The alignment of MMS with the Risk Based Approach was achieved by ADNOC LNG through successful implementation of Streamlined Reliability Centered Maintenance (SRCM) as a risk-based reliability asset integrity management tool. SRCM implementation achieved +98% reliability, cost reduction, work force utilization, proactive maintenance, and sustainable production. SRCM is mainly for rotating equipment, electrical equipment, and instrumentation. RBI (Risk Based Inspection) is already utilized for static equipment. The combination of both RBI and SRCM are successfully assuring the integrity of all assets at ADNOC LNG.
The key topics, which will be focused on, are criticality assessment, risk management, and asset integrity management reliability system SRCM (Streamline Reliability Centered Maintenance). The main challenges to implement MMS were: receiving the team's buy in, making sure the team was aligned with MMS policy and strategy, and cultural challenges. The system was successfully deployed with consistent processes and procedures helping maintenance end users perform in accordance to best practices.
A Novel Comprehensive Hysteretic Relative Permeability and Capillary Pressure Correlation
Authors: Cig Koksal 
Published: November 2020

Abstract
Relative permeability and capillary pressure (KR-PC) measurements from cores for a reservoir are a complex, labor-intensive and time-demanding job. Mathematical representation of KR-PC curves due to complicated multiphase flow mechanisms in situ is also a difficult task. Our objective is to achieve a comprehensive hysteretic KR-PC correlation in order to provide a better representation of the core driven KR-PC curves and apply them seamlessly for KR-PC history matching processes in numerical reservoir simulations.
The complications may arise from different rock types, wettabilities, transitional zones, saturation end-point differences, directional flow reversals and much more. For these reasons, there have been many KR-PC correlations developed to describe vast subtleties of reservoirs as well as to represent the KR-PC measurements from cores. KR-PC curves are later used in a variety of reservoir engineering, description and management applications.
The correlation proposed addresses difficulties observed in the commonly used correlations, such as: curve flexibility due to degrees of freedom to follow the measured data, hysteresis option by introducing scanning curves and satisfying the envelope of bounding curves, meaningful visual control points of complex curves, multiple flow reversal options from imbibition to drainage curves or vice versa, negative capillary pressure (Pc) values, which may occur in mixed-wetting conditions.
We have designed KR-PC curves from a simple parametrized cubic Bézier polynomial. The Bézier polynomial was further rationalized to provide weight factors to create required curvatures of the KR-PC curves. Hysteresis curves (either bounding or scanning curves) then added with a logical manner.
Generative Well Pattern Design Applied to a Giant Mature Field Leads to the Identification of Major Drilling Expenditure Reduction Opportunity
Authors: Lepphaille Maddalen , Thenon Arthur , Bergey Pierre , Salley Baptiste , Ben Sadok Abdelaziz , Koeck Charles 
Published: November 2020

Abstract
Well pattern design is difficult due to the very large number of possible solutions, the complexity of constraints deriving from drilling and completion, the nonlinear nature of fluid flow in porous media, the difficulty in ascertaining reservoir properties and, for mature reservoirs, development history. What matters the most is case dependent. This task is therefore traditionally conducted through manual processes with little or no help of computers, leading often to exceedingly conservative or simplistic designs whatever the reservoir heterogeneities.
The increase in computational power and algorithmic advances are opening the door to a new "Generative Design" approach, already used by other industries (car, aerospace). It consists in exploring a larger number of computer generated design possibilities more quickly and efficiently than what human can do by combining: i- "technical and experience" rules to automatically build a large number of "designs candidate", ii- workflows that qualify the performance of the designs, iii- selection criteria to identify the best design(s).
An innovative Generative Well Pattern Design Workflow named GWPD-WISH was benchmarked against traditional "manual" designs to leverage three reservoir development planning opportunities applicable to a giant mature middle eastern carbonate field already developed by hundreds of wells for which a reliable model was available:
Locate 2×15 in-fill producers to be drilled from 2 freely chosen platform locations Locate 2×15 in-fill producers to be drilled from 2 pre-determined platform locations Select 16 multi-string water injector wells for re-drill to improve recovery through better control of local reservoir pressure balance
The study was conducted using a large operational compositional model considering complex constraints in a limited time. The workflow proved able to identify substantially better patterns than the traditional approach for each of the three opportunities at the costs of only few hundreds of simulations. Pattern improvement was measured in term of reserves per incremental well and plateau duration extension. It corresponds to an opportunity for reducing drilling expenditures on a rolling basis by 30% or more.
High Accuracy Underwater Visual Measurement
Authors: Medagoda Lashika , Jolly Jordan , Bargoti Suchet , Kazzaz Abraham , Khan Junaid , Morgan Hamish , Altamimi Waleed , Ahsan Nasir , Naqshbandi Masood 
Published: November 2020

Abstract
Inspection of underwater assets on oil and gas offshore platforms are required to assess asset integrity, and whether intervention is required. These assets include mooring chains, fairleads, anodes and ballast tanks. Typically, calipers are used for taking measurements of these objects. Limitations of this technique include inaccuracy, inefficiency and potential damage to the asset. Compact underwater camera systems, including imaging sensors and lighting, are proposed to solve limitations of caliper measurements. Data processing creates scaled 3D models for measurement analysis and automatic fault detection. This paper presents Lantern Eye-S, a stereo-based visual measurement system developed by the authors. It is a stereo imaging system, which includes a stereo camera pair linked to a set of underwater strobes. It is extremely compact and can be deployed on very small ROVs, down to the 30kg class. Results are available as quickly as 5 minutes for in-situ analysis and assessment. Final results are available in 8 hours for detailed inspection. Calibration accounts for the water environment the images are taken, primarily to account for salinity in the water. Measurements can be automatically extracted, and comparisons are made to as-built drawings. Validation of the measurement is also undertaken with a known ground truth object placed in the water, to ensure integrity in the measurement.
Results include offshore integration and deployment on a mini-ROV (30kg class) and working class ROV (multiple tons). An important result from this work is that calipers were found to typically overestimate dimensions on mooring chain diameters. High accuracy measurements of small objects, with a compact camera system, was shown to be possible with the work in this paper. The use of a novel validation apparatus and uncertainty analysis allows appropriate levels of confidence to be attributed to the acquired analytics.
Identification & Mapping of Water Slumping Fronts by Ultra-Deep Electromagnetic Logging While Drilling Technology in Lower Cretaceous Reservoirs of Adnoc Onshore
Authors: Singh Maniesh , Al Arfi Saif , Boyd Douglas , Gerges Nader , Fares Wael , Clegg Nigel , Aki Ahmet , Diab Emad , Pandey Vikram , Mansoori Maisoon M. , Seddik Ibrahim A. , Reddy Rathnakar 
Published: November 2020

Abstract
ADNOC's limestone reservoirs suffer from the phenomena of injection water traveling preferentially at the top of the reservoir placing injection water above oil held there by capillary forces. Horizontal wells placed below areas of water override, cause the water above to slump unpredictably, increasing water cut and eventually killing the horizontal. Ultra Deep Directional Electromagnetic (EM) Logging While Drilling (LWD) tools provide the measurements to identify and map these water zones, improving reservoir management and design optimal well placement.
1D & 2D EM inversion modeling was conducted on two of ADNOC's largest oil producing reservoirs to evaluate the ability of an Ultra Deep Directional EM LWD Resistivity tool to identify water slumping in the presence of formation bed resistivity contrasts and predict depths of reliable detection (DOD) under various well trajectory scenarios. The inversion was run using depth of inversions up to 150 ft, the maximum expected vertical distance of tool to injection water. Modeling provided an optimized tool configuration (frequency, transmitter-receiver spacing's) to meet objectives. The inversion results further provided guidance for Geosteering, Geomapping and Geostopping decisions.
The inversion results in these reservoirs indicated that the Ultra Deep resistivity tool has a DOD of 50-150 ft to pick reservoir tops and water slumping or non-uniform waterfront boundaries. The real-time inversion will optimize landing and drilling long horizontal section to increase net pay for production and even through sub-seismic faults, measuring changes in the reservoir fluid distribution, reduce drilling risk and exceed well production life. This information will aid in updating static model with water flood areas, reservoir tops, faults and structure, designing better infill well spacing and trajectories within bypass oil regions, designing proactive and not reactive smart well completions to delay or reduce water production and ultimately extended plateau and improve ultimate recovery factor. Furthermore, it will aid resistivity mapping of underlying or overlying reservoirs for future development plans.
The encouraging results of this study confirmed to move forward with a field trial in these challenging reservoirs for better reservoir and fluid characterization and its management.