bluuebunny/crossref_metadata_2025_split huggingface dataset:
Construction of Mini Gas Processing Plants in the Conditions of Autonomous and Hard-To-Reach Oil Fields to Extract Gas Processing Valuable Components and Improve the Environment by Minimizing Gas Flaring
Authors: Chernoyarov Alexander 
Published: April 2024

Abstract
Currently, associated petroleum gas (APG) utilization, in order to minimize flaring, at oil and gas fields is solved by several classical methods:
Pipeline transportation of gas to consumers or large gas processing / chemical plants. LNG production and transport to the consumer. Utilization at oilfield power stations.
For autonomous oil and gas fields, the issue of gas utilization is especially acute if there is no infrastructure for transporting gas and its products to consumers, taking into account the economic feasibility of the project, in view of the high capital costs for classical gas processing plants.
Typically, classical gas processing plants are designed and constructed in large-tonnage scale, with a long feedstock profile, more than 15 years, to ensure the profitability of the project, due to the high cost of gas equipment. Often, the transportation of semi-products, such as NGL, from autonomous, hard-to-reach and small oil and gas fields is also unprofitable. Regarding this issue, APG utilization has to be carried out directly at the field by unprofitable methods - partial combustion, power generation, etc.
At the same time, APG is a valuable raw material in terms of obtaining products such as NGL, propane, butane and their mixtures. APG flaring has negative effects on the environment in the form of CO2 and other pollutant emissions, in this regard, the involvement of APG in processing even at small and autonomous fields allows the most efficient use of natural gas resources and improves the environment in the region.
Gazprom Neft Company implemented a mini gas processing plant with a capacity of ~ 4.25 MMSCFD for the processing of rich APG with the NGL production at an autonomous oil field, which made it possible to reduce APG flaring and send valuable raw materials (NGL) for processing together with oil. A separate infrastructure for the NGLs transportation was not been realized. NGL is transported by injection to on-spec oil, considering the RVP restriction. This decision helped to eliminate capital expenditures on the infrastructure for the NGLs shipment and transportation, which ensured the economic viability of the APG utilization project.
Mini Gas Processing Plant (NGL recovery) was implemented in modular form, which made it possible to place column and heat exchangers equipment with a minimum plotplant.
As a result of the mini GPP project implementation, a high APG utilization rate at the field was achieved - 99%.
Electrical/Electromagnetic Enhanced Oil Recovery for Unconventional Reservoirs: A Review of Research and Field Applications in Latin America
Authors: Rodriguez Fernancelys , Belhaj Hadi , Morales Raifel , Velasquez Richard , AlDhuhoori Mohamed , Alhameli Fatima 
Published: April 2024

Abstract
The exploitation of unconventional oil reservoirs with low environmental impact represents a big challenge nowadays, where considerable efforts are being focused on the production of clean fuels with low carbon content, and the energy transition to the net-zero carbon emissions. Electrical/electromagnetic Enhanced Oil Recovery (EEOR) processes have been considered emerging techniques that allow increasing mobility of crude oil along with reduced and low environmental impact, compared to well-known and established thermal techniques such as steam injection where significant volumes of water are required for steam generation, coupled with the high production of acid gases during these processes.
This article presents an exhaustive review of the Electrical/electromagnetic EOR methods evaluated at laboratory scale or investigated by numerical simulations, mostly undertaken for deeper understanding of the associated physical phenomena, as well as specific field-scale applications for several unconventional reservoirs in Latin America. In this context, the main challenges associated with the implementation of the process mechanisms and the application of these technologies along with the evaluation of applicable ranges of related critical parameters will be highlighted, and the main conclusions of laboratory experiences or/and field condition cases will be captured in this article.
Among the main results of this review, it is found that the application of Electrical/electromagnetic EOR/IOR methods offers advantages in increasing the mobility of crude oil without generation of high-water cuts as well as reduced H2S production, both having significant low impact environmental considerations. However, the common operational challenges and/or issues of these EOR techniques are related to process inefficiency due to the presence of high-water saturation, reservoir heterogeneities, electrical leakage, mechanical failures, tool's material characteristics, location of the heating, gas breakthrough and management of greenhouse gases, which pose limitations on the wide-spread use of these heating methods.
The paper will discuss important underlying aspects of the electrical/electromagnetic EOR processes to evaluate the viability of applying these methods in unconventional Latin American reservoirs, emphasizing Venezuelan reservoirs, based on technical and economic evaluations worldwide, targeting production of fossil fuels with low environmental impact from the huge hydrocarbon reserves located in Venezuela, mainly in the Orinoco Oil Belt.
A Digital Framework for the Integration of Simulation Prediction Profiles
Authors: Ciaurri D. Echeverria , Aqeel N. , Aldolijan W. A. , Salamah M. S. 
Published: April 2024

Abstract
In the oil and gas industry, vast numbers of simulations are commonly utilized to evaluate production scenarios for field development and business analysis and optimization. However, the process of compiling the obtained prediction profiles and of performing the required analysis is often carried out manually, which is not only time-consuming but also prone to errors. In this work, we present a framework aimed at automating the streamlined generation and analysis of the aforementioned profiles within a fully digital environment.
The workflow introduced conducts a comprehensive analysis of the input and output simulation files for each scenario. This includes temporal analysis and processing, such as the reporting of well drilling and activation, and installation of artificial-lift systems over time. Standardization of certain features is crucial to ensuring smooth automation. The framework allows for concurrent evaluation of multiple scenarios, making it suitable for distributed computing. It is important to note that profile archiving facilitates the creation of interactive dashboards for subsequent analysis and optimization. These dashboards can prove to be valuable tools in achieving desired business outcomes.
The proposed methodology was implemented using Python to extract and manipulate generic simulation input and output data and generate the prediction profiles. A standardization stage was performed beforehand by collaborating with the involved teams. The profiles had to be outputted in a pre-specified format and were subject to a series of validation tests. In all cases, the generated profiles were successfully validated. The computation time for a single profile, which typically takes several hours or even days, was reduced to approximately one hour and sometimes even less than that. It should be noted that parallel computing of all profiles can introduce an additional speed-up factor, reducing the wall-clock time frequently by at least one order of magnitude. The profiles were saved in a repository where data visualization and business-intelligence software could be utilized to extract various types of information for sound and robust decision-making, for example, through recommender systems that optimize capital expenditures and other costs.
The digitalization, integration and analysis of simulation output from a large number of scenarios can be a rather challenging enterprise due to the sheer volume and diversity of data generated by simulations. To overcome these challenges, advanced data analytics can be applied within a high-performance computing environment to extract meaningful insights and drive effective decision-making, enabling companies to stay competitive in an increasingly dynamic and uncertain market.
Advance Control System and Optimization OTSG MPC & Optimizer
Authors: Al Shueili H. H. , Asgharzadeh R. S. , Al Alawi R. , Al Adawi A. 
Published: April 2024

The Mukhaizna field in the Sultanate of Oman is a leading EOR in heavy oil recovery, where innovative strategies are continually sought to optimize production and minimize environmental impact. Among these strategies, the optimization of Once Through Steam Generators (OTSG) plays a pivotal role. This paper presents a comprehensive study on the implementation of an advanced control system and optimization strategies for OTSGs in Mukhaizna, aiming to enhance operational efficiency and environmental sustainability.
In recent years, the oil and gas industry has increasingly focused on reducing carbon emissions and optimizing resource utilization. The Mukhaizna field, characterized by its unique geological structure and operational challenges, provides an ideal setting to explore these objectives. This study outlines the deployment of a Model Predictive Controller (MPC) and Bank Optimizer, tools designed to maximize the thermal efficiency of OTSGs. The primary goal was to optimize steam quality and quantity, reduce fuel gas consumption, and, consequently, lower CO2 emissions.
It currently necessitates approximately 630K barrels of steam per day to satisfy its extensive steam flooding requirements. This substantial volume of steam is a critical element in the enhanced oil recovery efforts, ensuring the viability and longevity of the field's production capabilities. The generation of this steam is achieved through a combination of 13 Heat Recovery Steam Generators (HRSG) and 78 Once Through Steam Generators (OTSGs) arranged in Thermal Banks. This setup represents one of the field's most significant operational factors, underpinning the need for optimized control and management to maintain production efficiency and cost-effectiveness. The following discourse details the development of an advanced adaptive control system tailored to enhance the operation of these OTSG units, underscoring our commitment to operational excellence and environmental stewardship.
Geosteering and Monitoring Methods for Underbalanced Coiled Tubing Operations in Gas Reservoirs
Authors: Alsaud S. Abu , Katterbauer K. , Alshehri A. 
Published: April 2024

Abstract
Under-Balanced coiled tubing drilling (UBCTD) is one of the techniques used in developing low pressure gas reservoirs. However, a drawback in UBCTD is their limited geosteering and monitoring tools due to the coiled tubing size compatibility and hole dynamic condition. As such, we present a review of the current available geosteering and monitoring technologies that will help in achieving optimum geo-navigation through the gas sweet spot layers. In this work, a review of current geo-navigation and monitoring technologies for UBCTD operations will be demonstrated. After defining the associated challenges of steering with UBCTD, different technologies will be outlined based on their applicability and effectiveness in landing the UBCTD laterals in the sweet spot layers. These technologies are going to be in the form of downhole logging while drilling (LWD) tools (gamma ray and resistivity), real-time surface measurements, as well as cutting analysis like X-ray diffraction (XRD) and X-ray fluorescence (XRF).
Based on a thorough analysis of the different measuring methodologies, each one has its advantages and disadvantages, as follows: (i) The gamma ray measurement helps determine the lithology through the naturally occurring elements of the layers, but its reading doesn't effectively detect gas bearing zones. (ii) The resistivity reading helps in distinguishing conductive with non-conductive; however, good resistivity contrast between the layers needs to be present in order to distinguish layers that cannot be detected from the gamma ray alone. (iii) Gas flowback while drilling is an excellent indicator of gas presence, yet it doesn't directly indicate productive zones for better steering. (iv) Utilization of cutting analysis is the closest direct measurement of the reservoir, but its issue comes from its subjectivity, sample quality, and inconsistency in cutting depth correlation. As a result of the comparisons, we concluded that a combination of all the techniques is essential in achieving optimum well placement with UBCTD, where some technology weaknesses can be tackled with the other strengths.
This review represents a method of utilizing existing geosteering and monitoring technologies to advance UBCTD reservoir navigation capabilities by integrating different LWD, real-time measurements, and cutting analysis to achieve optimum lateral placement, yielding better field development and increased gas recovery.
Application of Hydraulic Fracture Propagation and Production Simulation Technology for Multi-Stage Optimization - A Case Study from Unconventional Reservoir
Authors: Zhang Jie , Lian Liming , Wang Peng , Li Guohui , Liu Zhiliang , Zou Guopeng , Tian Lei , Huang Xingning 
Published: April 2024

Abstract
Hydraulic fracturing technology, as an effective means to increase single well production, has been widely used in the production of various types of oil and gas reservoirs, achieving significant production enhancement. However, the heterogeneity of reservoirs determines that different reservoirs with different characteristics require different fracturing parameters. Using the same construction parameters for different reservoirs may increase operational costs and have adverse effects on production. In order to accurately obtain the optimal fracturing scheme, this study focuses on the following four aspects: 1) Regional geological research to accurately characterize the geological features of the reservoir; 2) Simulation research on the three-dimensional propagation of artificial fractures to visualize the artificial fracture network formed by different construction scales in three-dimensional space; 3) Numerical simulation research on productivity, combining the results of fracturing simulation to predict post-fracturing productivity; 4) Comparison and optimization of different fracturing schemes, considering factors such as fracturing construction cost, post-fracturing productivity, and effectiveness. The research results provide technical support for the design and optimization of fracturing schemes for production wells.
Steam Generation Using Renewables Energy - An Integrated Approach for Enhanced Oil Recovery Applications
Authors: Al Ajmi Mustafa , Al Lawati Abbas , Al Mayasi Arwa , Al Siyabi Idris , Al Lawati Mohammed , Al Harthi Shaikha , Al Hashmi Hamed 
Published: April 2024

Abstract
Petroleum Development Oman aspires to utilize the available renewable energy resources to produce steam for the Enhanced Oil Recovery operation in Amal oil field. The aim is to reduce the greenhouse gasses emitted from the current conventional steam production plants as well as reduce the dependency on natural gas for the process of generating steam. The paper also evaluates different types of renewable energy technologies against various value drivers in order to determine the optimum fit for purpose technologies that can be used for steam generation. In addition, it sheds light on the area selection process intended to host the proposed technologies. Finally, the paper discusses some of the operational challenges associated with the identified renewable energy technologies as well as states how such concepts can be further developed until realization.
Research and Pilot Experiment of Discontinuous Chemical Flooding Technology in Offshore Oilfield
Authors: Zhang Jian , Guan Cuo , Li Xianjie , Liang Dan , Zhao Wensen 
Published: April 2024

Abstract
Compared with conventional onshore oilfields, offshore oilfields have problems such as incomplete well pattern, large well spacing, strong heterogeneity, and high crude oil viscosity. Conventional chemical flooding methods have limited ability to control and drive, and relying on a single chemical agent system cannot avoid fingering and channeling in the presence of dominant pores and fractures. In order to continuously and evenly development the reservoir, it is necessary to study the discontinuous chemical flooding technology with the purposeful alternate combination of multiple chemical systems as the core. Firstly, the static properties and flooding characteristics of chemicals such as gels, microgels and associative polymers commonly used in discontinuous chemical flooding in offshore oilfields are evaluated. The concept of reservoir displacement equilibrium degree is established by comprehensively considering the sweeping conditions of every sub-layers and the oil displacement effect of the sub-layers. Based on this, combined with the physical simulation experiment of parallel core flooding, a simulation study is carried out on the adaptability of discontinuous chemical flooding and the production status of sub-layers in the process of discontinuous chemical flooding. Finally, Combining the indoor physical simulation test results, a pilot experiment plan for discontinuous chemical flooding in offshore BZ oil field is formulated. The basic performance of the chemical system commonly used in conventional chemical flooding is obtained through the experiments, and the systems are divided into three levels: strong, medium and weak according to the adjustable flooding intensity, which provides necessary parameter support for the efficient use of the chemical in the process of discontinuous chemical flooding. Through physical simulation experiments, the design principles and application specifications for obtaining discontinuous chemical flooding equilibrium production are given, which can provide theoretical guidance for practical field applications. Since the discontinuous chemical flooding in BZ oil field, the effect of oil increase has been remarkable. The peak daily oil production of a single well has increased by 115%, and the maximum reduction of water cut is 15%, At the same time, the effective time is more than five months. Discontinuous chemical flooding in offshore oilfields is a new development method that combines multiple technologies to "relay" flooding. This technology can efficiently improve oil production speed and oil production effect in the whole process of oilfield development, greatly shorten oilfield development time, in the shortest time to obtain maximum yield and economic benefits.
Enhanced Deep-Resistivity Measurement and High-Resolution Multilayer Inversions Improve Geosteering and Reservoir Mapping Performance Offshore UAE
Authors: Bourgeois Daniel , Suleiman Sameh Yahyia Ali , Siddiqui Wamiq , Burnely Syed Hammad Ali , Bautista Ramiro Oswaldo Vasquez , van Vliet Francois , Braganza Reinhard , Goddyn Xavier , Moreira Luis , D’Cruz Melroy 
Published: April 2024

Abstract
Dubai Petroleum Establishment (DPE) has been developing a field offshore UAE using directional drilling and logging-while-drilling measurement services. Multiple horizontal wells are being drilled to develop this field, and due to the thickness and complexity of the target reservoir, the wells are being geosteered with deep-directional resistivity measurements to map the target boundaries. While successfully drilling these wells while remaining in the target, the previous generation of measurements did not enable mapping of the target top over the entire section. In 2023, a new deep- directional propagation resistivity tool was introduced to improve geosteering decision making while drilling horizontal development wells.
Although deep and ultradeep propagation resistivity measurements from various tool configurations have been used for geosteering and reservoir boundary mapping for several years, the resistivity inversion is challenged as reservoir complexity and distance to boundary increase. The new technology introduces deep, calibrated resistivity measurement from a tilted antenna at farther spacing than typical resistivity measurements. This provides the deeper depth of investigation required to map the top of the target in this formation. In addition, deterministic inversions have been applied to the measurements, in contrast to the Monte Carlo-type inversion used in previous generations of deep- directional resistivity measurements. Deterministic-based inversions have shown better resolution when deployed for ultradeep propagation resistivity tools that use a wider spectrum of measurement spacing and frequency but have not previously been used for deep-resistivity tools.
The introduction of this technology improved the depth of investigation for mapping reservoir boundaries in this field and target intervals by 80%, allowing for earlier and more efficient decision making, which resulted in a smoother wellbore with fewer undulations. The target formation drilled with this new technology has several thin, clinoform features, dipping at a high angle relative to the overall formation dip. Using the high-resolution multilayer inversion with these deeper measurements, these clinoform features could be mapped, providing a better overall understanding of the reservoir.
The introduction of enhanced deep resistivity measurements and a high-resolution inversion allowed for improved geosteering and reservoir understanding to develop this offshore field.