bluuebunny/crossref_metadata_2025_split huggingface dataset:
Constructed Wetland as an Alternative to Conventional Industrial Wastewater Treatment to Promote Carbon Sequestration for Sustainable Future
Authors: Tan Sew Keng , M Shah M Faris , Sufian Suriati , Chai Pui Vun 
Published: February 2023

AbstractConstructed wetlands (CW) are man-made systems that mimic the natural wetlands. They can be used for various purposes, including wastewater treatment, stormwater management, and carbon sequestration. Wetlands naturally absorb and store carbon from the atmosphere, and CW can replicate this process by using plants and microorganisms to remove and store carbon from the water. Conventional wastewater treatment plants (WWTP) use more energy and contribute to carbon emissions, so many industries are looking for ways to reduce greenhouse gas (GHG) emissions. While CW have been widely used for municipal and sewage treatment, their use as an alternative or supplement to industrial wastewater treatment, particularly in the oil and gas and petrochemical industries, is limited. However, CW have the potential to promote carbon sequestration and have a lower cost of capital and operating expenses compared to conventional WWTP, while also emitting lower GHG emissions. A case study is presented for two types of system in which one is actual operating conventional WWTP in Malaysia design and operate at 60m3/d and a hybrid CW of equivalent treatment capability and capacity. The case study found that GHG emissions from a conventional WWTP were approximately 3.75 times higher than the hybrid CW system with the same treatment capacity. For a small capacity WWTP at 60m3 per day, converting the treatment system from conventional WWTP to CW will reduce approximately 45.7t CO2 eq per year based on Life Cycle Assessment (LCA) calculation. The conventional WWTP consumed much higher power especially from the air blower compared to CW where limited number of equipment is required. The additional carbon sink for CW from carbon sequestration from plant, soil decomposition and sediment has not been quantified in the LCA calculation. Hence, it is expected the actual CO2 eq emission for CW is much lesser than the conventional WWTP. With all the benefit identified and the proven success case in several places, the adoption of CW as an industrial WWTP should be widely promoted as the replacement of conventional WWTP for sustainable future.
Drilling Weak Formations in Rumaila Field in Southern Iraq — Modelling Shear Failure Using Numerical Models
Authors: Al-Asadi Yousif M. B. , Nasreldin Gaisoni , Al-Shahwan Muwafaq F. J. 
Published: February 2023

AbstractThe giant Rumaila oilfield in south Iraq has been plagued by a number of wellbore instabilities. The shaley formations in this field pose the greatest challenges to drilling operations, accounting for approximately 90% of the problems. Stuck pipe, tight hole, and borehole collapse are examples of the incidents commonly encountered even while drilling vertical and deviated wells.This paper presents a well planning tool for translating the geomechanics simulation results to operational parameters, and in so doing, informing well trajectory planning and optimization. Specifically, the main objective was to generate shear failure mud weight cubes for different trajectories, The scenarios considered focused on examining the impact of depletion on field performance, drilling and well completion integrity for making life-of-reservoir decisions. The mechanical properties were first estimated along the trajectories of multiple 1D mechanical earth models (1D-MEMs) byutilizing available rock mechanics testing results, followed by geostatical populationin 3D space. The final 3D-MEM was calibrated against field observations.
Qualification Tests of OCTG Premium Connection under Cryogenic conditions for CCS projects
Authors: Nutricato Giacomo , Repetto Carmen , Brambilla Ruggero , Dal Forno Luca , Santoro Domenico , Nunzi Paolo , Martini Luca , Eaton Roger , Piccolo Aureliano , Zambetti Raffaello , Cordero Jorge , Goya Martin J. , Santi Nestor J. , Gibellini Erica 
Published: February 2023

Abstract
In a global context aiming to unlock a low carbon future by industry decarbonization, developing the infrastructure for capturing and storing CO2 emissions is a key target of countries, energy companies and regulatory bodies. Injection for geological storage in suitable reservoirs is an advantageous option which presents challenges related to the completion accessories and string exposed to the injected fluid and the thermodynamical loads during injection and the well life.
The purpose of this work is to simulate by numerical analysis and full-scale test, the behavior of a gas-tight Metal-to-Metal OCTG premium dope-free connection when subjected to low temperatures and loads generated by the effect of a sudden CO2 high pressure drop during injection in depleted reservoirs. Extreme temperature drop down caused by the Joule-Thompson (J-T) effect between injection conditions (P-T) inside the tubular and those in the annulus, may expose tubing connections to a thermal shock reaching a temperature near the theoretical figure of -78.5°C. This temperature drop assumed as worst-case scenario is also explored. The analysis is performed considering estimated loads for a CO2 injection case study.
The numerical analysis and full-scale test performed confirm the structural and sealability performance of the connection is not affected by the exposure to such low temperatures. Additionally, transient thermal loads, with a drop of approximately 100°C, appears to be not critical for the metal-to-metal dope-free seal integrity and also not affecting the structural integrity of the connection. The challenges setting up of a prototype testing frame, simulating the cooling by thermal shock, lead to a methodology for assessing CCS projects premium connection able to define a robust testing protocol for cryogenic temperatures. The numerical and full-scale results collected on the tested connection size, together with the ones previously tested, allow extrapolation to near sizes of the same premium thread family.
The results achieved by testing a premium connection which has been subjected to a thermal shock approaching -78.5°C represent a forefront in the industry, demonstrating the reliability of the product not only in operative conditions during CO2 injection, but also after an extreme event, assessing performance for the CCUS storage projects.
Revitalizing Vintage 3D Land Seismic Dataset Using Advanced Signal Processing and Imaging Techniques: A Success Story from Onshore Central Thailand
Authors: Wanpiyarat Napat , Chakraborty Rupam , Ng Seng Hor , Phantawee Namfon 
Published: February 2023

Abstract
We present a case study on the application of modern signal processing and depth-imaging techniques to vintage land seismic data from the Phitsanulok Basin, onshore central Thailand, in which four overlapping 3D surveys were pre-migration merged and imaged to form a single volume. The legacy data processing was limited to the application of dip-filter-based noise attenuation, pre-stack time imaging and post-stack survey merging, which leads to unresolved geophysical challenges associated with each process. In this study, a cascaded application of surface-wave and coherent noise attenuation was followed by a surface-consistent deconvolution that is suitable for stabilizing the amplitude and phase response of the embedded wavelet. Then, we applied a 5D matching-pursuit Fourier interpolation technique for interpolation and regularization in the offset-vector tile domain of the sparsely and irregularly sampled data. Finally, anisotropic depth imaging was implemented to reduce structural uncertainty. Our results show that the modern processing workflow further enhances continuity and accuracy of structural images, overcoming the limitations imposed by the vintage acquisition parameters. As a result, these improvements will reduce the risks associated with future development plans.
Business Intelligence Platform Applied to the Interdisciplinary Management of Subsurface Data Integration
Authors: Sanasi Carla , Amicosante Marco , Mezzapesa Domenico , Marfella Ferdinando , Pagani Riccardo , Gentile Erika , Bucci Alessandro , Crottini Ada 
Published: February 2023

Abstract
Over the last 3 years, Eni has developed an integrated platform to gather subsurface data and make them available to the final users across the company. The Platform is structured in four data domains including the well data, which is the focus of this abstract. In the data model, the well master and architectural data assume paramount importance since they are upstream of the value chain and represent the aggregator of all the data recorded in the well. A large amount of data coming from all Eni Affiliates and operative sites is produced daily. To gather, perform Quality Controls and ingest them, Eni has implemented a governed workflow to ensure data is made available to the final users through the platform in an efficient and transparent way.
The workflow aims to ingest the well master and well geometrical data directly from the well site defining roles all along the data transmission chain, with the ultimate objective to ensure the proper data quality once they reach the cross-functional subsurface data platform. It is no less important the timely availability of such data to guarantee a prompt association with geological and drilling log data. Given the increased amount of data acquired from disparate data sources, different functions and locations, Business Intelligence tools have been designed to monitor the workflow combining data for an easier data insight. To manage such complex network, dedicated dashboards allow all the users involved to visualize the status of the processes through specific KPIs, thus optimizing communication and reducing the human effort required.
The capability to manage, validate and quickly interpret data will determine the competitive advantage among Energy Companies in the next future. Eni targets to excel in the everchanging business environment leveraging the new century asset: the data.
The presented approach, combined with the diffused data culture initiatives, promotes a collaborative environment, and increase awareness on data importance across the value chain.
An Automated Workflow of Simplified Representative Elementary Volume (SREV) Approach to Sand Prediction and Control Monitoring (SPCM) Using Web-Based Interfaces to Reference with Operation Efficiency Improvement in Zawtika Field, Myanmar
Authors: Dhadachaipathomphong Supha-Kitti , Sooksawat Prapong , Toprasert Pooritat , Peerakham Chatchanakorn , Lertrojanachusit Nattapong , Nazir Fahd , Wang Fengjuan , Pattinama Melani , Dai Jiajun , Lihawa Mohammad Taufiq , Chaiyasart Chaiyaphruk 
Published: February 2023

AbstractThe oil and gas industry has been plagued by formation sand production for decades because of negative impacts on wellbore stability and equipment, despite the fact that it has been demonstrated to be a highly effective technique to increase well productivity (Wang, J. et al., 2004). The consequent sanding problem of sand production has been conducted, wearing down production equipment and necessitating environmentally acceptable disposal criteria. The sand production from unconsolidated sand formations in shallow depth have been reported 10% to 40% sand cuts with 5% in heavy oil reservoir (Tremblay, et al., 1999) and averaged 40% in light oil reservoir (Papamichos, et al., 2001). The objective is to increase operation efficiency of sand monitoring and control by using a sand prediction model to estimate sand production per well based on current operating conditions, as well as to calculate sand operating envelope for each well to guide the production planning and management. Vardoulakis I. and et al (1996) were the first proposed the hydro-erosion model based on rigid porous media in 1996. The erosion models were extended to include the effect of the deformation of porous media in a consistent manner (Wan and Wang, 2002) and include a fully coupled reservoir-geomechanics model as representative elementary volume (REV) to account for the effects of multiphase flow and geomechanics in a consistent manner (Wang et al., 2004). Methodology was starting from data collection, conducted Simplified Representative Elementary Volume (SREV), Integrated Asset model of well, model calibration, monitoring, integration of well, facility for prediction of sand accumulation and wall thickness condition. In addition, a data driven was imbedded to integration as well as workflow automation and user surveillance dashboard in web-based interfaces. The calibration process has been proved the models results with greater than 90% accuracy of sand production. It was found that SREV and IAM approach to sand prediction and control monitoring (SPCM) successful gave an improvement in operations efficiency by reducing time spent on manual analysis and decision-making process through dashboards with predictive results.
Multi-Stage Fracturing Seepage Model and Productivity Prediction Method for Horizontal Wells in Shale Oil Reservoir-Use Horizontal Wells in Qingcheng Oil Field, China, as an Example
Authors: Ma Shuwei , Li Jian , He Youan , Liu Changchun , Lei Qihong , Huang Tianjing 
Published: February 2023

AbstractShale oil in Ordos basin, China, is being developed using horizontal well and volume fracturing. Elastic energy, dissolved gas expansion etc. are the main driving forces for fluid flowing from matrix to horizontal wellbore. However, flow mechanism varies greatly when hydrocarbon flows from matrix to artificial fractures and then to wellbore, due to huge differences in the sizes of flow channel, from nano-scale pore-throat in matrix to meter-scale channel in wellbore. Thus, a reasonable mathematical description of the structural characteristics of complex fracture networks is important for an accurate productivity prediction model of a horizontal well. In this paper, a physical model was first built dividing fluid seepage area into three sections and five small zones, which are horizontal wellbore zone, highly transformed zone, weakly transformed zone, drainage zone in matrix and the non-drainage zone in matrix. Joukowski transformation was then introduced before a mathematical solution was deduced, where law of equivalent seepage resistance and material balance method were applied. Then mathematical model of seepage in five different zones were built based on the solution considering different flow patterns, threshold pressure gradient and stress sensitivity in those zones. Productivity equation of multi-section-coupled seepage flow in three sections was deduced afterwards and came up with a fast calculation method to predict productivity in horizontal well with multi-scale nonlinear characteristics by solving analytical solutions for multistage mathematical models. The method has been applied to simulate dynamic development performance in 67 horizontal wells (have been producing for over 3 years) in Qingcheng oil field, Ordos basin, China, with an 82.01% of accuracy. The developed simulation model is expected to be applicable not only in the prediction of development performance in horizontal wells in shale oil and gas reservoir but also in other unconventional reservoirs such as carbonate reservoirs. The process may shed light on the ways to increase the total productivity of oil and gas recovery in hydrocarbon industry.
Pilot Installation of Ceramic Coated Through Tubing Sand Screen Installation in Gas Producer Offshore Malaysia
Authors: Ibrahim Kamal Sarah Nabilah , B M Zin Zulkifli , Kamarul Zaman Nur Hazrina , A Rahim M Shamir , Rosland Eadie Azahar , Salleh Khiril Shahreza 
Published: February 2023

AbstractWell X, a gas producer located in offshore Malaysia had to be beaned down and subsequently shut in due to sand issues after 7 years of production through pressure depletion. It was completed in cased and perforated completion without any sand exclusion and has been producing since 2014. The evaluation on the sand control solution for Well X prioritizes remedial downhole sand control that is able to withstand highly erosive environment due to its high fluid velocity. As such, a ceramic coated Through Tubing Sand Screen (TTSS) was installed in 2021 and successfully reactivated the well to produce with minimal sand.A series of qualification testing was conducted during the technology evaluation to demonstrate the ceramic coated TTSS resistance towards erosion and corrosion i.e. Gas Screen Erosion Test (GSET), Corrosion Test and Mechanical Strength Test. Studies on erosional velocity, Particle Size Distribution (PSD) and production analysis were conducted to determine the wire wrapped screen slot size and ensuring the mixture velocity is within the screen operating envelope.Upon installation, the well performance was monitored using Acoustic Sand Monitoring (ASM) sensor and Online Sand Sampler (OSS) during the initial flowback and continued using manual spot sampling at the multiphase flowmeter. The screen retrieval was planned after 4 months flowing period for evaluation and the same screen was reinstalled as it was in good condition and met the inspection criteria. The installation of the ceramic coated Through Tubing Sand Screen (TTSS) at Well X has successfully demonstrated its resistance against erosion with good production and sand control performance.This paper will share on the overview of the ceramic coated TTSS including the analysis on screen design selection, screen retrieval findings and well performance post TTSS installation.
A New Approach for Reservoir Connectivity Assessment and Flow Assurance Prediction Applying Reservoir Fluid Geodynamics
Authors: Ighodalo Endurance , Berkane Mustapha , Mattar Tariq , Abdulmoniem Mohammed 
Published: February 2023

Abstract
Traditional approach relys on reservoir pressures to assess reservoir connectivity in low permeability formations. This paper will present a new approach of applying Reservoir Fluid Geodynamics (RFG) through Flory Huggins-Zuo (FHZ) equation of state (EOS) for asphaltene distributions to determine reservoir connectivity and fluid typing in undrilled locations.
FHZ-EOS asphaltene gradient was constructed with data from downhole fluid samples in different wells covering two zones (A and B). The downhole fluid analysis (DFA) results were validated with laboratory analysis. The structural continuity of both zones across the study area in the field was validated using a wide range of geological data including conventional open-hole logs. The resulting FHZ-EOS model formed the basis for fluid typing, correlation and connectivity across layers. The DFA data was used in real time at different stages of formation fluid sampling cleanup to correlate the samples quality with the existing model.
The DFA data used in real time in conjunction with the pre-built FHZ-EOS model, improved the sampling quality check process and confidence in the sample quality, especially in the presence of low gas oil ratio (GOR) fluids. This improvement in real time data quality helped to optimize the pumping time and reduce the number of samples in each reservoir since the confidence in the sample quality was high. The constructed asphaltene gradient from the FHZ-EOS model also confirm the hydrocarbon continuity both vertically and laterally in undrilled locations with the study area of the field. For each of the zones, the data analysis shows a clear and distinct asphaltene gradient with different asphaltene molecule sizes. This supports the presence of heavy oil / tar towards the deeper sections of the area of interest within the field. It also predicted the depths / location of the heavy oil / tar, which will assist in the field development plan and flow assurance.
Integrated Measurement and Control Technology for Intelligent Artificial Lift Based on Multiphase Flowmeter
Authors: Chen Guanhong , Deng Feng , Chen Shiwen , Shi Junfeng , Jiang Weidong , Ma Gaoqiang , Wang Cai 
Published: February 2023

AbstractIntermittent oil recovery is a direct and effective way to reduce energy consumption and improve recovery efficiency. However, the existing open and shut-in well procedure relies on manual control, which has problems such as increased labor costs, changeless intermittent parameters, poor energy saving, and also brings hidden dangers to wells. As multiphase flowmeter can detect fluid supply status of oil wells in real time, it could be a significant tool for intermittent production design.This paper proposes a multiphase flow online measurement technology based on magnetic resonance, which can measure the production and composition of a single well in real time, with high frequency and accuracy. A set of oil well intelligent control system is developed to realize remote well open and shut in, and automatic and controllable intermittent oil production. A relationship model of well production data, open time and intermittent time is described by the machine learning-based algorithm. While the model is installed on wells, it can automatically learn and constantly refine the model to intelligently design an intermittent process.The proposal of this technology integrates a single well from parameter measurement, data analysis to intelligent control, forming an intelligent closed-loop control of the artificial lift system. While reducing the accident rate, it has achieved maximum energy saving and efficiency improvement. This technology has achieved good results in field applications, with a power saving rate of more than 20%.This technology is an important part of oilfield intelligence and automation and is an important step to improve the level of delicacy management of single wells and enhance the digital construction of oilfields. At the same time, the technology does not involve any information such as electrical parameters, indicator diagrams, etc. Thus, it can be extended to other forms of oil production wells other than pumping wells to improve production efficiency, save energy and reduce consumption, and realize the safe and sustainable development of oil fields.