bluuebunny/crossref_metadata_2025_split huggingface dataset:
Industrial Implementation of Emulsion-Suspension System with Nanoparticles for Oil and Gas Wells Completion and Maintenance
Authors: Sergeev Vitaly , Tanimoto Kenji , Abe Masashi 
Published: November 2020

AbstractAn article presents comparative results of pilot of an innovative blocking pack for well-killing operation – emulsion-suspension system with supercharged nanoparticles (ESS). The ESS is characterized by the following competitive advantages: unlimited compatibility with petroleum reservoir fluids, gases, rocks and well-killing brine, adaptability of specific gravity in a wide range (900-1400 kg/m3), foreseeable rheology, alteration of wettability of rock surface, reversibility of blockage, no harm to downhole equipment, system of oil and gas gathering and environment. The ESS blocking pack pilot was carried out in multifractured horizontal wells under high-pressure (39.5 MPa) and high temperature reservoir conditions (115 °C) of Tortasinskoe oil-gas field, Western Siberia, Russia. The reservoir rock of Tortasinskoe oil-gas field is sandstone, characterized by low permeability (0.001-0.0001 μm2) and porosity (13%). A comprehensive laboratory tests program was executed for ensuring successfulness of the ESS blocking pack pilot in the complicated reservoir conditions of Tortasinskoe oil-gas field. The laboratory tests program included a basic research and specific experiments. The results of pilot confirmed significant competitive advantages of the ESS blocking pack in comparison with a synthetic polymer blocking pack, which was unsuccessfully applied earlier on the same production well. The ESS blocking pack showed high performance for well-killing operation in complicated HPHT reservoir conditions than widely used worldwide synthetic polymer system did not work at all.
Natural Fractures Sensitivity to Hydraulic Fractures in Abu Dhabi, UAE
Authors: Noufal Abdelwahab 
Published: November 2020

Abstract
Fractures serve as important conduits for subsurface fluid flow and their presence can transform an otherwise unproductive rock formation into an economic hydrocarbon reservoir. Natural fractures have a vivid impact on reservoirs, especially the low perm, as they control the hydraulic flow as conductors (open fractures) or barriers (sealed fractures). Abu Dhabi carbonates are dissected by many fracture clusters, but most of them are sealed, therefore it is critical to investigate, which sets are predicted to reactivate. Hydraulic fracturing in horizontal drilling are the primary enabling technology to gain economical production from the low perm reservoirs. However, fracture parameters are poorly constrained by reservoir data, due to they are subseismic and hard to predict their behaviour through the life-cycle of the reservoir. Addressing the structural patterns and using the geomechanical data along well bores help to assess their roles in production enhancement and sensitivity to hydraulic fractures initiation and propagation.
The spatial distribution of microfaults, hybrid fractures and pure opening mode fissures with wide variations in strike appears related to their location with respect to the deformation zones of the nearby fault segments in the reservoirs of Abu Dhabi. Usually not all fracture sets enhancing production and the best approach is to predict those sets that playing these roles.
The ability of fractured bedrock to transmit fluids depends upon the physical characteristics of the fractures and opening-mode fractures that make up the fracture system, such as fracture aperture, fracture length, fracture density, fault displacement and gouge thickness. Many of the hydraulically significant fractures at the reservoir scale cannot directly detected, neither by borehole imaging tools nor by seismic imaging. Thus, reservoir characterization, in terms offracture architecture models, are derived from a combination of well data and the factors that control fracture development in carbonate reservoirs of Abu Dhabi. These factors include stratigraphy, rock properties, kinematics, especially orientations and mechanics of fracture growth and principally their relation to the present day in situ stresses.
The results showing that, hydraulic fractures propagation is dependent on the natural fractures and bedding planes orientations and the well location relative to the fault segments deformation zones. Understanding and predicting the behavior of fractures involves the identification and location of hydraulically significant fractures. Such fractures are conduits for fluid flow, and are connected to other hydraulically conductive fractures to form conduit systems. Conductive fracture networks may include a large number of interconnected hydraulically active fractures, or may be limited to a very small proportion of the total fractures in the rock mass.
Control System Integration with Multiple Vendors Supports Drilling Optimization Software Application
Authors: Jeffery Christopher , Creegan Andrew 
Published: November 2020

Abstract
This paper details the integration of a software drilling optimizer to multiple drilling rig control systems. The drilling optimizer operates via communication of auto-driller setpoints to the rig's control system, continuously adjusting parameters to be optimum to wellbore conditions, and detected drilling dysfunctions. The integration process with each vendor's control system requires planning and work on both sides of the integration to ensure seamless communication of data. Integration performed over the last two years with three different control systems from two vendors was completed using various communication protocols.
The authors found that when a centralized process management solution, acting as a data broker between applications and the control system was present, the individual rig deployment configuration and installation effort was minimal. The study showed when performing direct integration to the control system; there is an increase in the configuration and installation effort for each rig deployment. Each rig required specific customization by engineering resources from both the software provider and the rig control system vendor. The development of user interfaces across different platforms creates an additional layer of synchronization to ensure the user experience is consistent. By ensuring consistency in each implementation of the user interface, the authors observed a reduction in training for the field support teams.
The project concluded that there is a need to centralize custom and complex user interface elements to improve the usability of the application for the driller. With the use of a centralized process management solution, companies can now minimize user interaction at the control system to avoid duplication of effort in design and engineering. The standardization of hardware to run the drilling optimizer simplified the deployment process and improved business efficiency.
The lessons learned from these processes contribute to the overall industry initiatives around data interoperability. These projects have laid the foundation between control system providers and software providers to increase the efficiency of future projects that necessitate data transfer through multiple communication standards.
Integrated Reservoir Model History Matching Workflow: Unlocking Reservoir Opportunities, Onshore Abu Dhabi, UAE
Authors: Setiyo Pamungkas Talla Gueye 
Published: November 2020

Abstract
Reservoir model history matching is the solving process of a complex inverse equation mainly relating reservoir and well properties to observed data using a time and space discretized numerical model. A challenging task for engineers but a prerequisite to a vital tool to field development and business planning. This paper presents the calibration of a giant Middle East carbonate reservoir from scratch following a major field review. The objective of this integrated history match was to provide a reliable and sustainable representation of the reservoir in order to:
Predict performance, necessary strategies and expenditures for field development Reproduce the fluid distribution and the flow mechanism Represent the areas of the reservoir where there are no data Discover then solve or anticipate any operational issue
It is a tedious work to calibrate coherently the static and dynamic models of a Giant field with complex geological heterogeneities, more than a thousand wells and forty-four years of history where multiple scenarios can coexist. This paper will present the workflow used to achieve a reliable and sustainable representation while narrowing down the number of solutions by using:
Theoretical and analytical calculations on paper to assess the foundation and physics behind the reservoir behavior Phenomenological models to understand the main drivers and reproduce the flow mechanism with a more flexible tool Regional geology and migration history to estimate untested parameters away from the oil pool especially inside the aquifer An iterative and innovative Static-Dynamic integrated process to generate a reservoir characterization honoring geology and performance at the same time
The applied workflow revealed for the first time the magnitude of the natural energy of the reservoir that contributes significantly (15-20%) to the energy loss. A revelation that changed the reservoir development strategy going forward. It inspired innovative methods to capture horizontal and vertical permeability needed to reproduce field performance on surface and flow dynamics inside the reservoir.
This comprehensive and integrated workflow generated a reliable and sustainable tool and put in place different technics to achieve an updated history match relatively quickly.
Blended Acquisition with Temporally Signatured/Modulated and Spatially Dispersed Source Array: The First Pilot Survey Onshore Abu Dhabi
Authors: Ishiyama Tomohide , Zhao Mingqiu , Hu Fei 
Published: November 2020

Abstract
We recently introduced a blended-acquisition method: temporally signatured and/or modulated, and spatially dispersed source array, so-called S-/M-DSA. This method jointly uses various signaturing and/or modulation along with dispersed source array each in the time and space dimension.
We just acquired and processed the first pilot survey with S-/M-DSA onshore Abu Dhabi. In this paper, we review the resulting acquisition-productivity enhancement in the time dimension, and discuss it in the space dimension as well. We then review the deblended-data-reconstruction processing, and discuss its results and performance. We last establish a relationship between the acquisition productivity and the deblended-data-reconstruction performance.
We found that S-/M-DSA significantly enhances the acquisition productivity compared to conventional blending methods. For the deblended-data reconstruction, the deblended data can properly be reconstructed, with a high repeatability over the full frequency band, from the blended data. This method owns a relationship: the deblended-data-reconstruction performance increases with the acquisition time (inversely proportional to the acquisition productivity) in general, up to a plateau to be reached in cases of conventional blending methods with much longer acquisition times.
Performance Comparison of Two Different In-House Built Virtual Metering Systems for Production Back Allocation.
Authors: Vitale Fabio , Oliva Marco , Montini Marco , Ponteggia Luca , Ursini Fabrizio , D'Addato Francesco 
Published: November 2020

Abstract
A virtual metering system is an alternative way to measure the flow rate of a well in real time. They can therefore improve the reliability and the effectiveness of the production back allocation process, providing redundancy to multi-phase flow meters (MPFMs) measures.
Scope of this work is to build and validate two different virtual metering systems highlighting their peculiarities and comparing their performance.
A virtual metering system can estimate the flow rates of each well of an asset by elaboration of pressure and temperature data coming from the field.
In both virtual metering systems, the core is a fluid-mechanical model of the production network of the same off-shore field, made of six wells flowing in two parallel lines. The model is run multiple times adjusting the wells flow rates according to two different minimization algorithms, to match the measured data as much as possible.
After validating the results, the performance of the tools has been compared against MPFMs, used as a common reference.
Both systems have been validated against officially allocated flow rates coming from MPFMs. At first, only pressure data have been used as inputs.
System number one, which exploits the Matlab minimization algorithm and an OLGA model of the network, showed great accuracy in the majority of the cases, with an error less than 5%, making it a great verification tool for measures coming from other instruments. Its simulation runtime, however, is still too long to make it usable in a real-time application scenario.
System number two relies instead on the gradient descent algorithm and on a GAP model of the network. This system is equipped with an automatic tool that can discard unreliable signals coming from damaged or out-of-calibration field sensors, while simulating. The resulting accuracy is acceptable, with an average error between 5% and 8% and the computational time is short enough to be used as a live measurement tool, in parallel to MPFMs.
The validation process has been repeated adding temperatures to pressures in the input dataset. No accuracy improvement has been shown by the new results for both systems, concluding that a leaner structure where only pressure is considered is to be preferred.
The two systems represent economic measurement tools for production allocation, showing a good ability in supporting field operation in case of instrument failure or unreliability.
Potential Utilization of Neutron Logging Technology for Casing Cement Evaluation - Feasibility Study
Authors: Dommersnes Espen , Khalifeh Mahmoud , Larsen Helge B. 
Published: November 2020

Abstract
Reliable cement evaluation is crucial for well integrity and optimal production. Current cement evaluation technologies have limitations and a fundamental analysis is performed to assess neutron logging for this purpose. Basic modelling has been performed to study neutron transmission for several realistic cases including good cement, channeled cement, foamed cement and through-tubing configurations. For a comprehensive review, other aspects such as health, safety and environment (HSE), cost and alternative approaches have also been assessed.
Results achieved show that neutrons have the potential to travel to the cement-formation interface and return to the detector without being completely attenuated. For single casing configurations, results indicate that cement channels produce distinguishable results from intact cement. For through-tubing logging it cannot be concluded that detected results are distinguishable. Even though neutron logging itself is likely to be more costly than cement bond logs, potential benefits in terms of other cost savings and decrease in HSE risks must also be considered.
First Successful Installation of Washpipe Free ICD Completion with Dissolvable Materials: An Optimized Design for Middle Eastern Fields
Authors: Corona Cortes Georgina , Ashraf Hamza , Kouadio Yao 
Published: November 2020

Abstract
Inflow Control Device (ICD) completions have been used widely in the energy industry to balance the inflow of produced fluids, while delaying water breakthrough. Improving the reservoir drainage results in higher oil recovery. Traditional completions are typically deployed with washpipe to provide washdown and circulation capability. This is especially advantageous for Run In Hole (RIH) through tight spots and extended-reach wells. A tailored ICD design with dissolvable materials was tested and optimized for Middle Eastern fields with the first successful installation in UAE of a washpipe-free ICD completion.
The washpipe-free adjustable ICD completion utilizes a combination of permanent and dissolvable temporary ICD plugs. A range of dissolving materials were developed and tested in a variety of representative downhole conditions, including temperature and pressure variables. The dissolvable materials were tailored specifically to suit the fluid program and fluid additives, common to the Middle East. Multiple plug designs were subjected to small-scale and full-scale tests. Computational Fluid Dynamics (CFD) simulations evolved the design of the ICD housing to ensure that the dissolution fluid would reach the ICD plugs.
The dissolution rates of the dissolvable materials were empirically established at representative downhole temperatures with field fluid samples. The degradation and pressure integrity of the materials was validated in small- and full-scale testing. Through full-scale testing, the operational sequences during RIH including displacement and filter cake breaker spotting were replicated with representative pressures, fluid rates, bottom hole temperatures (BHT), and fluid compositions used in the Middle East field.
The validated ICD plugging rod technology was successfully run in the UAE in an extended-reach horizontal well. The permanent plugs allowed for customization of the completion inflow profile as per the most recent logs, while the dissolvable temporary plugs provided a completion string with pressure integrity while running in hole - capable of washdown, circulation, and filter cake treatment placement. After installation, the temporary plugs dissolved, opening the completion to production through the ICDs for improved reservoir management.
The ICD with dissolvable technology allowed deployment of the completion successfully to target depth (TD) with the pressure integrity required for the displacement operations. In not running and retrieving an inner string, and achieving wellbore displacement at a faster rate, time savings for the 6000 ft OH completion were estimated between 35-50 hours, with an estimated cost saving of a half-million dollars.
Looking into the Deep: Seismic Reservoir Characterization for Understanding the Offshore Early Permian Clastic Reservoirs in Abu Dhabi
Authors: Caeiro Maria Helena , Al Kobaisi Abdulla , Parra Humberto , Tavares Julio , Lopez Diego 
Published: November 2020

AbstractWith the current increase of domestic and global demand for gas, exploring any gas accumulations has never been more attractive in Abu Dhabi. The deepest targets, such as the clastic Permian formations, are especially attractive due to their H2S free (sweet gas) characteristics. Nevertheless, understanding the deep reservoirs is still one of the main exploration challenges in Abu Dhabi. The primary Pre-Khuff reservoir potential within offshore Abu Dhabi is considered to lie within the siliciclastic deposits of the Unayzah Fm. The Unayzah Fm. comprises predominantly continental deposits ranging from alluvial fan, braided river, lacustrine facies in western Saudi Arabia to fluvial, eolian, overbank and interdune facies further east. Deltaic to shallow marine deposits are also present in eastern Abu Dhabi and Saudi Arabia.Seismic reservoir characterization poses as one of the most significant options for understanding the reservoir architecture and properties. Pre-stack seismic inversion was conducted targeting the Pre-Khuff zone of two offshore fields in Abu Dhabi. The available seismic data is a full azimuth high-quality 3D ocean bottom cable (OBC), covering 1270km2, with wide radial offset range of approximately 9400 meters. Due to the long offsets, four partial angle stacks (up to 40° of mid angle) processed to relatively true amplitudes, after pre-stack time migration, allowed the extraction of seismic reflectivity information at the deep sections with confidence. Elastic properties were derived from seismic reflectivity data and reservoir properties were sub consequently obtained. Although the inversion resolution was led by the seismic bandwidth, lateral continuity of inverted properties (P-impedance and Vp/Vs ratio) benefitted from the good seismic coherency of reflectors and signal to noise ratio. The comparison between the recorded seismic and the inverted synthetics exhibited a high cross-correlation throughout the whole area, for all partial stacks.The novelty of this study is the applicability of pre-stack seismic inversion techniques to the characterization of deep clastic reservoirs in offshore Abu Dhabi. The final products represent valuable information not only for further qualitative analysis in terms of reservoir geometry interpretation but also to derive some reservoir properties that could potentially optimize future exploration and appraisal activities.
30 Days to 36 Months Plus Operation-Reliability Improvement Journey of Integrally Geared Compressors
Authors: Pasha Khalifa , Kumar Rajeeva 
Published: November 2020

Abstract
Maintaining the high level of reliability of Instrument Air compressor is essential for safe operation of Oil and Gas facilities however challenges remains to maintain high level of reliability in integrally geared design instrument air compressor due to exceptionally high speed (50,000 rpm) and minimal clearance bearing..etc. This paper presents success story of such compressor`s Reliability and MTBF improvement from 30 days to more than 36 months.
Integrally geared compressor was installed and commissioned in year 2002 as facility upgrade project and never run continuously more than 30 days due to frequent high vibration trip and lead to consequence Risk of plant operation and upset due to non-availability of compressorExtremely high maintenance cost &gt; $120,000 per year due to repeated maintenance intervention
Identifying the common vibration malfunction like unbalance, misalignment, rubs, cracks, shaft bows are relatively easy, as the behavior/characteristics of these problems are well understood, however challenge remains for identifying the rare uncommon problems with limited information so this paper details interesting achievement of, how we diagnose and eliminate vibration issues.
Structured root cause analysis of high vibration revealed cause of high vibrations are Bearing Frosting /Pitting contributed by buildup of Electrostatic current and discharge through bearing High residual magnetism, and compounded by Yellow deposits /varnish formation due to thermal oxidation which is result of high operating temperature and Oil disintegration.
To eliminate above uncommon problems, following solution were identified as. Installation of current diverter rings (CDR) in motor, which avoided development of high shaft voltage from either motor or compressor by discharging to the ground.Removal of residual magnetism from rotor by On Site degaussing process.Maintained the lube oil supply temperature less than 60°C by upgrading the temperature control elements.To identify varnish formation, Perform proactive varnish potential test like membrane patch colorimetric (MPC)
Implementation of above recommendations enhanced the equipment uptime with reduced maintenance effort and cost, which permanently resolved the high vibration issues and made the compressor reliable for uninterrupted supply of instrument air to process plant without major overhauling for more than 7 years as of now.