bluuebunny/crossref_metadata_2025_split huggingface dataset:
Simulation Model for Optimization of Gas Production System Through Integration of Sub-Surface and Surface Facilities
Authors: Mumtaz Yasir , Ur Rehman Awais , Junaid Shaikh Muhammad 
Published: November 2018

Abstract
Mari Gas Field; discovered in 1957, is one of the oldest and mature fields of Pakistan and currently the highest gas producing field of the country. Mari Field has vital role in ensuring the food security of Pakistan as it is meeting gas needs of 87% of Fertilizer Industry. Field has been developed in multiple phases with 97 producing wells and complex gas gathering network of 284 km. In recent past few years, the country's supply and demand gap for gas is on widening trend. In order to support national energy needs, MPCL management decided to take initiative of executing gas incremental and optimization drive for playing its part in meeting the crucial energy demand of country. Furtermore, it was also matter of great importance to sustain the enhanced production plateau and meeting production & revenue targets.
Multidisciplinary teams were formed for evaluation of complete system from Reservoir to delivery end. Integrated approach was adopted for assessment of system at existing state of production and targeted production rate as de-coupled models would have not served the purpose well in this particular case. This study covers the integration of sub-surface and surface facilities; linking reservoir simulator at IPR Level, through in-house simulation model developed in commercial simulator. Keeping in view the target of study i.e. incremental and sustained production, reservoir rates were constrained and hence semi-implicit approach was used instead of fully implicit modeling which saved a lot of computation time and avoided complexities. Coupled model was simulated for predicting futuristic behavior of system at enhanced production which identified bottlenecks and integrity problems in existing system and also proposed the solutions through series of sensitivities analysis. This exercise triggered the proactive approach for solving system issues and kicked-off proper surveillance of system which are mandatory to sustain the desired production plateau and ensure the mechanical integrity of system. This study further emphasized that evaluation of complete system through integrated modeling can save compression cost at by de-bottlenecking the existing infrastructure.
At present, the field is producing at 20% incremental volume over and above of initial base volume and future plans have also been formulated to sustain the production plateau as per reservoir simulator.
Use of New Wireline Conveyance Technologies on an Offshore Abu Dhabi Well Saves Significant Rig Time and Results in Improved Sonic and Nuclear Magnetic Resonance Data Quality
Authors: Brindle Frank , Rafique Maqsood , Thatha Rajesh , McCormick Stephen , Escott Samuel , Bajwa Haroon , Cocagne Michael 
Published: November 2018

Abstract
Drill Pipe conveyance (TLC/PCL) of wireline logging tools or Logging While Drilling (LWD) is usually required for high deviation / high differential sticking risk logging scenarios. These are costly in terms of rig time and service company costs. This paper details how a full suite of high-quality open hole log data was obtained on wireline in a high angle 16,500ft wellbore utilizing a new conveyance system and a polymer-locked high strength cable.
The new conveyance system, utilizing wheeled carriages and a holefinder with nose angled upwards, takes a holistic approach to tool conveyance, reducing drag while ensuring both correct tool orientation and optimum contact and standoff for each logging service. Management of tool centers of gravity relative to the wheel axes ensures correct orientation. The reduction in friction due to wheeled carriages vs weight and cable load is modelled before the operation in order to ensure successful runs, both into and out of the wellbore. Polymer-locked high strength cable significantly increases maximum safe pull capability and enhanced data transmission technology allows faster logging speeds, greater rig time efficiency and reduced sticking risk.
The wheeled carriage system enabled conventional logging in a high angle well, minimized stick-slip and reduced differential sticking risk. The unique holefinder prevented tool hold up during descent. The Vertical Seismic Profile (VSP) run (the only run not able to utilize the system due to tool size and design) was held up on a ledge above the lowest reservoir of interest. The high strength cable allowed safe retrieval of tools (over-pull &gt; 6000lbs) in one particularly sticky zone.
In a world first, an array sonic tool was centralized through management of weighted and eccentralized tool sections using bespoke wheels. This eliminated the drag inherent to traditional methods of sonic centralization (centralization using powered calipers and/or spring centralizers), resulting in excellent data quality. Nuclear Magnetic Resonance logs were obtained by orienting the tool sensor with wheels which utilized tool weight to provide sensor application force. This removed the need for additional centralizers, resulting in data devoid of stick-slip artefacts (an issue in previous wells).
The formation fluid sampling run was conveyed on drill pipe, taking 6 days of rig time. There are further significant efficiency gains to be had on future operations by using the new conveyance system on sampling tools (operators have already moved in this direction in the Gulf of Mexico).
Maximizing Pipeline Flexibility with Drag Reducing Agents
Authors: Johnston Ray , Lee Yung 
Published: November 2018

Abstract
Drag reducing agents (DRA) have been applied to pipelines since they were first commercialized by Conoco, Inc. in 1979, and have proven to be a reliable tool for the pipeline industry. Over the past 40 years, adoption of DRA has been widespread across the globe, in a broad range of climates and in a variety of hydrocarbon fluids.
DRA are valuable tools as they can reliably provide flexibility in the operation of a pipeline. Because DRA can be applied over a range of dosage levels in the pipeline, they offer a range of options in terms of operating points at higher flow rates or lower pressures. DRA can be used to substantially increase flow rate in a capacity limited pipeline, or maintain flow rate in a derated line. They can also be used for energy savings, bypassing pump stations. DRA can bring substantial value to pipeline operations through aversion of flow loss, and through minimizing capital and energy costs.
The latest generation of DRA have demonstrated very high performance potential in terms of drag reduction performance and supply logistics. New pipelines are increasingly considering DRA usage and flexibility during the design stage, which can minimize capital and operating costs.
First Implementation of Real-Time Subsurface Monitoring for Cuttings Reinjection Offshore Abu Dhabi
Authors: Gumarov Salamat , Benelkadi Said , Bianco Eduardo , Woolf Shaun , Hardy Chris , Ido Hisataka , Tanaka Manabu , Tominaga Naohiro , Yahata Kazuhiro , Okuzawa Taker 
Published: November 2018

Abstract
Management of drilling wastes presents major challenges during drilling operations in environmentally protected areas. An Abu Dhabi offshore field development project selected cuttings reinjection (CRI) services as an appropriate solution for waste management.
Although CRI is a proven technology in the region, fracturing injection always inherits its own containment-related risks. To prevent all possible failures that were experienced earlier in the industry globally, a novel real-time monitoring and analysis of fracturing injections data was introduced.
A comprehensive front-end engineering design (FEED) study was performed to evaluate the feasibility of CRI techniques by selecting a suitable injection formation and designing a CRI-dedicated well, surface facilities, slurry testing, and appropriate operations execution plan.
The CRI well was drilled and completed to accommodate waste volumes. An assurance program based on industry best practices was used to support zero solids settling, fracture, or perforation plugging.
To achieve on-time intervention, the first real-time CRI data transfer through a satellite-based network to a support center staffed by global experts in Abu Dhabi was deployed to analyze fracture injection and shut-in pressure responses for early identification of possible risks and to map the fracture waste domain.
The project has been operated successfully since its inception with more than 300,000 bbl of drilled cuttings and drilling waste fluids injected since July 2016. No injectivity issues were experienced during drilling waste fluids injection. Several on-time interventions had been made to prevent well plugging and to maintain surface injection pressures within normal ranges.
Real-time data streaming has made a step-change improvement in the data delivery process, monitoring, and fracture pressure analysis. It creates a direct link between the wellsite and worldwide multidisciplinary technical expertise centralized in Abu Dhabi and provides visualization capability at any time and to any where to all personnel involved in the project.
This step change in monitoring CRI operations provides an acquisition-to-answer" integrated solution, mitigates the injection risks, and enhances the intrinsic value of CRI services.
The paper shares the experience of implementing the novel real-time CRI subsurface injection assurance program dedicated for cuttings reinjection operations. Real-time support from multidisciplinary experts provides live injection monitoring and fracture waste domain mapping for highly complex and risk-prone subsurface injection environments with stringent regulations
Edge Analytics at the Wellhead: Designing Robust Machine Learning Models for Artificial Lift Failure Detection
Authors: Boguslawski Bartosz , Boujonnier Matthieu , Bissuel-Beauvais Loryne , Saghir Fahd 
Published: November 2018

Abstract
This paper outlines the challenges and constraints related to deployment of Machine Learning solutions for rod pump abnormal states recognition and diagnosis at the wellhead. Those abnormal states may lead to a failure or to non-optimized production. Particular focus is on two main aspects: 1) Develop a robust Machine Learning model & IIoT architecture to predict rod pump failure directly at the wellhead, 2) Ensure high level of pump failure prediction through Machine Learning to ensure operator confidence.
To the best of our knowledge, this is the first-of-its-kind IIoT Edge Analytics solution which provides operators with the capability of automated Dynagraph Card recognition directly at the wellhead via Machine Learning models. This solution also addresses end-user requirements in terms of confidentiality and communication infrastructure.
Standalone Cased-Hole Formation Evaluation and Uncertainty Propagation to Increase Well Deliverability in Challenging Environments
Authors: Vinci Fabio , Pirrone Marco , Galli Giuseppe , Macaluso Daniela , Rocco Francois , Zarauti Roberto 
Published: November 2018

Abstract
In new wells with hole stability problems, which require to be cased and cemented immediately, and in old wells without a complete or reliable log dataset, a formation evaluation by means of quantitative open-hole (OH) log interpretation is not possible. Cased-hole (CH) logging can represent the only solution, despite being usually considered highly uncertain. This paper discusses the standalone use of CH logs, integrated in a probabilistic framework, for petrophysical characterization and uncertainty propagation purposes.
The approach consists of a full statistical workflow aimed at a formation evaluation with only CH logs as input, also including capture cross-sections, carbon/oxygen ratios and inelastic spectra. Several wells with complete OH petrophysical characterization have been used to define the rate of success of this methodology in different scenarios. Furthermore, a Monte Carlo framework is introduced to account for the uncertainty quantification of the CH outputs. The final outcome is the set of probability distribution functions of the petrophysical properties, the most probable scenario and the associated uncertainty.
Three real operative applications, in scenarios with no OH logs available, are presented: an old well without a complete/reliable OH log dataset (gas- and oil-bearing sandstone reservoir with variable salinity), and two new wells with hole stability problems (in a sandstone and in a carbonate oil-bearing reservoir at high formation water salinity). In the latter cases, numerical simulations are performed to correctly handle mud-filtrate invasion effects for a robust modeling also in the shallow zone investigated by CH logs. In all these challenging conditions, a complete formation evaluation has been obtained, and successfully used to select proper intervals to perforate. The increased hydrocarbon production driven by the outcomes of the standalone CH characterization further validates the efficiency of this method.
Though CH logging is a well-known technology in reservoir monitoring, its successful standalone use for reliable formation evaluation can represent an important step forward in reservoir characterization processes, in all those cases where OH data are not available or too risky to acquire. Finally, the value of uncertainty analysis has a huge relevance for appropriate production optimization and reservoir modeling strategies.
Pore-Scale Network Modeling of Petrophysical Properties in Samples with Wide Pore Size Distributions
Authors: Hakimov Nijat , Zolfaghari Arsalan , Kalantari-Dahaghi Amirmasoud , Negahban Shahin , Gunter Gary 
Published: November 2018

Abstract
Archie's law is commonly used for the estimation of petrophysical properties of porous media linking electrical resistivity to water saturation. Therefore, low resistivity formation is expected to have high water saturation and hence, high water production. This, however, is not the case for many reservoirs around the world, for which low resistivity pay zones have been reported with very low or none water cut.
One of the main causes of Low Resistivity Pay (LRP) phenomena, especially in carbonates, is microporosity. Due to their small pore sizes, micro-pores have much higher threshold capillary pressures than macro-pores during drainage in the water-wet samples which resembles the original state of reservoirs before oil migrations. Because of that, we often find formations in which micro pores and macro pores are saturated with brine and oil, respectively. This indicates that there is a correlation between pore fluid occupancies and pore size distributions. The existence of connected pathways through micro-pores that are fully saturated with a conductive phase (i.e., brine) creates ‘shortcuts’ for the electrical current which causes short circuit and, ultimately, lowers rock resistivity measured from log analysis.
The purpose of this work is to investigate the impact of microporosity on the electrical properties of porous media through pore-scale network modeling techniques. To achieve this, a tortuous pore network is constructed on 2D rectangular regular lattice to represent macro pores and throats in the network. Next, the macro network is modified to include micro-pores. This has been done by adding a small rectangular lattice network of micro pores and throats. Radii and lengths of each element are chosen from the pre-specified ranges. This is done carefully to ensure that all networks of different scales fit geometrically within the lattice of a given size. We are specifically interested to investigate flow and electrical properties as a function of the locations, dimensions, and orientations of the micro-porosity regions. To achieve this goal, a comprehensive set of sensitivity analyses are done to assess the impact of various parameters including number of pores, tortuosity, geometry and location of microporosity (i.e., parallel or in series, continuous or non-continuous). The results are compared against Archie's equation, which is commonly used in the industry for log interpretation. This work helps to further expand the use of this equation for field applications, specifically, for formations containing rocks with wide pore size distribution.
Talent Management Strategies, Programs and Results
Authors: Al Yaarubi Hilal Abdullah 
Published: November 2018

Abstract
The objective of this paper is to share Occidental Oman's Talent Management strategies, development programs, and the results achieved on the ground. The focus will be on three major pillars; (i) understanding the adopted talent management strategies/framework and the value chain as we materialize the strategies on ground, (ii) hiring strategies, and (iii) ensuring we are developing the required talent development programs to accelerate the learning and time to autonomy.
To give the audience a better understanding of our adopted talent management strategy and our sustainable nationalization program, I'll present one of the successful heavy oil projects as a business case, the Occidental Oman Block 53 Mukhaizna Project. Block 53 is a heavy-oil field (approximately 15.5 API). An oil field of such nature requires a unique set of technology and equipment to get the oil from the ground. Accordingly, Occidental Oman constructed one of the world's largest and most advanced mechanical vapor compressors, also known as MVC. Considering that Mukhaizna is the only MVC in the region, and taking into account the unique technology/equipment utilized in the project, there was an understandable lack of knowledge and expertise in the local and regional market. As a result, Occidental Oman had to develop a hiring and skills development strategy to be able to commission and operate the project to achieve the required targets.
The comprehensive framework adopted by Occidental Oman to support this project considered the three main pillars highlighted below, which resulted in supporting the business with the required workforce, as well as ensuring the development of local capabilities for the project.
A New Collaborative Workflow to Optimize Well Placement in the First Unconventional Horizontal Well in the United Arab Emirates
Authors: Fares Wael , Aki Ahmet , Essam Ramy , Vican Kresimir , Negm Ehab , Van Laer Pierre 
Published: November 2018

Abstract
A horizontal well was drilled in an unconventional source rock for the first time in the United Arab Emirates using advanced logging-while-drilling (LWD) high-resolution microresistivity and near-bit gamma ray imaging sensors. The well plan required locating a ±3 ft true vertical thickness (TVT) source rock sublayer; this sublayer was located within a giant undeveloped unconventional carbonate reservoir in a middle Cretaceous carbonate sequence onshore Abu Dhabi. Additional planning and drilling challenges included the absence of offset wells in this field and the associated structural geological uncertainty. Consequently, a vertical pilot hole was drilled to evaluate the local geological structure and to determine the reservoir properties.
For source rock reservoirs, a unique and collaborative approach has been developed that enabled the associated specific challenges to be addressed. This approach was built on reservoir knowledge to help determine where and how to drill, as well as where and how to fracture, to optimize each stage of the field development.
A well placement and geosteering methodology/workflow was developed and applied. This workflow used azimuthal high-resolution microresistivity and near-bit azimuthal gamma ray sensors to land and geosteer the well within the thin target layer, while maintaining the planned trajectory with minimum borehole tortuosity using real-time drilling optimization. The high-resolution microresistivity images were analyzed to classify image patterns to correlate to reservoir units for further field development and to better understand the reservoir flow units. The laterolog resistivities were also determined to be better suited for inferred Rt and Rxo measurements for petrophysical formation evaluation than the modeled electromagnetic wave resistivity inverted values.
The well was successfully drilled, and the geosteering objectives were achieved with 100% reservoir contact. The field development strategy for the horizontal drain in the undeveloped source rock is being reviewed, based on these recent data, to benchmark and optimize well placement, formation evaluation, and production technologies, to evaluate the economic potential of this unconventional reservoir.
This paper presents a case study after completing the first unconventional horizontal well in the UAE and describes the integration of fit-for-purpose geosteering technologies and optimized drilling performance to maximize reservoir contact and improve reservoir insight. Benchmarking of cost effective well placement and petrophysical data gathering requirements for the future field development program are also discussed for maximizing asset value.
Virtual Reality in D&C: A New Way for Immersion Training and Operation Simulation
Authors: Maliardi Alberto , Ferrara Paolo , Poloni Roberto , Spagnolo Salvatore , De Marchi Eliana , Grasso Tiberio , Allara Paolo 
Published: November 2018

Abstract
Nowadays the use of Virtual Reality is quite common in many fields of technology and consumer market. For drilling applications, it is mostly used for rig crew training on Drilling Simulators1 or virtual touring of site locations. Moving from this state of the art, Eni, in collaboration with Saipem, developed a new portable virtual system for training immersion and operation simulation in order to improve: rig & equipment knowledge and operation know-how, support and safety awareness.
A last generation semi-sub rig, for deep water drilling, was fully virtualized integrating four main characteristics: walk-through rig and equipment,operation play back,safety interaction,well simulation
The System takes advantage of a field database of more than 300 drilled wells, while well simulation is to be interfaced to dedicated command modules including a remote location driller cyber-base.
The System is accessible on PC, in dedicated 3D-rooms and with suitable virtual reality headsets. It has been initially used for enhancing the training of new drilling engineers and supervisors, with possibility to improve their safety induction as well as rig and well operation knowledge through immersive experience on various drilling events. The System also includes a collaborative environment that is useful for immersive and realistic training but that can also be used for well planning, operation preparation and field support. As a complement to global approach in conventional planning, it is possible to locally analyze and experience in advance various specific and complex drilling operations and events, with the aim to optimize them, prevent problems and enhance operation safety.