Day 2 Tue, November 01, 2022最新文献

{"title":"Application of Computer Vision in Diagnosing Water Production Mechanisms in Oil Wells","authors":"Osama Elsayed Abdelaziem, A. Gawish, S. Farrag","doi":"10.2118/211804-ms","DOIUrl":"https://doi.org/10.2118/211804-ms","url":null,"abstract":"\u0000 Diagnostic plots, introduced by K.S. Chan, are widely used to determine excessive water production mechanisms. In this paper, we introduce a computer vision model that is capable of segmenting and identifying multiple Chan signatures per plot, for the sake of surveillance and early screening, given that wells could exhibit diverse mechanisms throughout their lifecycle.\u0000 As deep learning demands a vast amount of information, we start our workflow by building a dataset of 10,000 publicly available oil wells that have experienced varying water production mechanisms and annotating them. Next, we perform pre-processing and remove anomalies from production data, which could be misleading in analysis. Then, we visualize Chan plots as images, split the dataset, carry out augmentation, and have the data ready to be used as input for a CNN (Convolutional Neural Network) layer. Eventually, we utilize YOLO, a one-stage object detector, tune hyper-parameters and evaluate the model performance using mAP (mean average precision).\u0000 The collected data from fields in Alaska and North Dakota represent oil wells that have been producing for decades. When working with some wells that possess noisy production data, we identified challenge, bias, and tedium in human interpretation of Chan plots. Subsequently, we observed the inevitability of cleaning well production data prior to constructing the plots, and thoroughly revealed its effect on enhancing the potentiality to get a satisfactory score. In addition, we concluded that following a simple approach of active learning, a technique that allows the user to analyze mistakes of prediction and label the data incrementally in order to achieve a greater score with fewer training labels, accomplished a significant boost in model performance especially with under-represented classes. The newly proposed model employs automatic feature extraction, expresses data in much more detail and is confirmed to be robust as it successfully predicted multiple mechanisms of excessive water production, with confidence scores higher than 80%, in wells that exhibit different production conditions such as horizontal trajectories, artificial lift, water flooding, stimulation, and other well intervention events.\u0000 In this work, we introduce a novel computer-vision model, which combines image processing and deep learning techniques to identify multiple water production signatures that a well can undergo, and eliminate the subjectivity of human interpretation. This approach has the potential to be effective, as a part of workflow automation, in expeditious surveillance of large oilfields.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121304685","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integrated Absorption and Regeneration Membrane Contactor Technology for Removal of CO2 and H2S from Natural Gas","authors":"Athirah Mohd Tamidi, Syafiqa M Saleh, Ven Chian Quek, Mahmat Rashid Hanafiah","doi":"10.2118/211216-ms","DOIUrl":"https://doi.org/10.2118/211216-ms","url":null,"abstract":"\u0000 Regeneration of rich amine using membrane contactor (MBC) is studied with observation on factors of operating temperature, flowrate and pressure. The desorption of CO2 and H2S were analyzed, and as a result operating pressure and liquid temperature were identified as the most significant parameters affecting desorption. Higher acid gas flux was observed at higher temperature and higher flowrate. Desorption of CO2 at higher flowrate is limited by the membrane contact area; whilst H2S was more readily desorbed. The higher operating transmembrane pressure of 0.3 barg is preferred as it provided good control during regeneration operation. The optimized parameter for rich amine regeneration was determined through ANOVA analysis using DesignExpert software. The optimum condition was found to be at 90 °C and 0.3 barg; these parameters were then used for the integrated operation of the absorption and regeneration membrane contactor. Continuous integrated testing was carried out and successfully met the specification for both sections. The absorption membrane contactor was able to remove CO2 from 25% down to 6.5% and H2S from 500ppm to below 20ppm. The regeneration section maintained good desorption of H2S where the recycled amine had less than 200ppm and for CO2 desorption 0.2 mol CO2/mol amine loading was removed.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"294 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121408191","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Achieving Productivity and Operational Efficiency, and High-Quality Data Through Automation in Well Log Data Quality Control and Acceptance Process Using AI/ML Techniques","authors":"B. Akbar, H. Al-Aradi, P. Achmad, Waqar Ullah Khan","doi":"10.2118/211173-ms","DOIUrl":"https://doi.org/10.2118/211173-ms","url":null,"abstract":"\u0000 Well log data and reports volume generated by oilfield operations in Kuwait Oil Company (KOC) have increased tremendously over the last decade. Currently, KOC receives around 100 to 200 well log packages every week. Each package may contain hundreds of well log files. Mostly, the processes to receive, manage and load this amount of data into the Corporate Database were manual, involving 7 to 9 resources. Logging companies may have to wait a minimum of a week to receive the decision if their data delivery is approved or rejected. The Exploration and Production Information Management (E&P IM) team started an initiative to accelerate and automate these processes by developing and implementing a solution using Artificial Intelligence and Machine Learning techniques to increase productivity and operational efficiency and achieve high-quality data. The main results are high-quality data that meet E&P IM Well Log Standard and Specification, the processing time is reduced by 80%, and the operational efficiency is improved by 66%, allowing the resources assignment to more valuable activities.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"22 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114835092","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Oil Rim Development by Waterflooding: Lessons Learned from the South Turgai Basin Case Studies","authors":"A. Mukanov","doi":"10.2118/211322-ms","DOIUrl":"https://doi.org/10.2118/211322-ms","url":null,"abstract":"\u0000 Characteristics of two brown oil fields in the South Turgai Basin Field pose challenges for field development. Oil rims bounded by a gas cap on one side and an aquifer on another side are present in both fields. These features coupled with poor rock properties make the development of these fields challenging. As a result, enhanced recovery techniques are necessary for the economic production of oil and gas.\u0000 Accounting for high saturation pressure and weak aquifer reservoir pressure maintenance is considered critical for the oil rims, as these have been observed twofold reduction in reservoir pressure from the initial one. To account for such effects, previous producing wells were converted to gas and water injection wells. Gas flooding of the gas cap is performed using a crestal injection pattern and water injection into the gas-oil zone is used to create a water bank between the gas cap and oil rim. Moreover, waterflooding is launched by peripheral water injection with additional advantages attained from gravity segregation.\u0000 Changes in oil and gas production have been observed as a result of pressure maintenance. First, the gas injection implemented in the wells located 1.5-3 km from the oil rim have prevented gas breakthrough in producers, despite the significant injection rates. High injection rates are a result of the governmental ban on flaring, since this prompts engineers to perform faster pressure recovery and target a higher volume of utilization. Second, crestal and edge water injection have different results in different parts of the fields. However, in some cases rim flooding have devastating effects as producers have been watered out. On one hand, the goal of decreasing the gas production was met, which happened earlier and was one of the biggest challenges facing the company. Consequently, gas-oil ratios decreased almost ten times than what they were previously. On the other hand, water-cut on many producers increased substantially, up to 90-95%, and in some areas top injectors even killed the down-dip producers. Thus, despite having solved one problem, another one emerged. Overall, crestal water injection (i.e., barrier waterflooding) is risky, and requires stricter regulation and management.\u0000 Case studies from the South-Turgai Basin show that water injection in top structure of oil rims for enhanced oil recovery can lead to positive as well as negative results. Overall, the paper demonstrates the cause-and-effect relationship of the previously described impacts of such water injection and provides recommendations for proper waterflooding management in oil rims based on the success in other parts of the field.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126374459","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Digitalization and Data Automation: The Path for a More Efficient Well Integrity Data Management and Cost-Effective Responses","authors":"Mouna Nizar","doi":"10.2118/211225-ms","DOIUrl":"https://doi.org/10.2118/211225-ms","url":null,"abstract":"\u0000 Bridging data management gap by gathering all well integrity data in one unique data base. The aim of ADNOC Offshore in-house Well Integrity Data Management System (WIDMS) is to comply with the 3A rule: Accessibility of the data, Accuracy by performing regular quality check and Analysis. The analysis allows to maintain wells barriers robust, to ensure personnel safety and to quickly identify integrity issues to make qualified decisions about appropriate mitigations measures and avoid risk escalation. WIDMS has been developed in-house with inputs and collaboration of various stake holders. An enhancement list has been established selecting the most relevant features that will be added value to the system. Therefore, Automation for sub processes like thresholds calculations and Risk Assessment which gives input for Well Passports that contains all the required information to evaluate the well risks and implement the required mitigation measures.\u0000 End users are following a RACI Chart to keep WIDMS database on track and to ensure no data falls through the cracks as all the data workflow is defined through the different steps such as providing data, entering it in the system, informing relevant stakeholders and providing technical clarifications if needed. The result of data acquisition in WIDMS is that data flows across the entire organization, with defined access rights in line with ADNOC Offshore policies. This data is collected from various sources, is a robust data base, essential for evaluating and maintaining well integrity.\u0000 It is enhancing well barriers system management by allowing to have full overview of well's barriers performance. Moreover, it allows to have reliable and continuously available data such as annulus pressure data that is critical for well integrity assurance, to avoid the uncontrolled release of hydrocarbons to the atmosphere. Notifications have been implemented so alerts can be sent for engineers to inform about any abnormality and non-compliance. As technology evolves, using paper-based processes, excel spreadsheets, time-based equipment inspection and testing become less effective. Well diagnostics are expensive so utilizing well data analytics through this digital hub project will ease having detailed real time data and quick analysis for early detection of failures and anticipation and reduction of risk escalation.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126560630","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Iron Sulfide Chemical Dissolver Deployment in Water Wells","authors":"Nasser M. Al-Hajri, Sulaiman T. Ureiga, Muhammad Imran Javed, Saleh J Marri","doi":"10.2118/211311-ms","DOIUrl":"https://doi.org/10.2118/211311-ms","url":null,"abstract":"\u0000 This paper will introduce a pioneering Iron Sulfide (FeS) chemical dissolver. The novel chemical dissolver can be used for descaling applications in oil and gas wells. However, the particular scope of this paper would be to outline an operational well intervention workflow for a successful deployment of FeS dissolver in water wells.\u0000 Iron sulfide scale presence in the wellbore is challenging to oilfield operators. Unlike other common scale types, such as Calcium Carbonates, FeS scale does not dissolve easily in Hydrochloric Acid (HCl) and the FeS/HCl reaction produces the dangerous Hydrogen Sulfide as a reaction product. Accordingly, oilfield operators resort to mechanical descaling of the FeS in order to restore wellbore accessibility. Mechanical descaling has disadvantages that include high cost, the need to flowback downhole milling returns, and possible damage to downhole tubulars. Alternatively, the novel chemical described in this paper can be used to effectively descale the wellbore without exposing the oilfield operator to the setbacks that could encountered from mechanical descaling. This paper will outline operational steps to execute a flagship descaling operation. The operational steps include pre-job diagnostics, job design and contingencies, as well as expected results and outcomes.\u0000 The proposed FeS dissolving chemical has successfully met all laboratory and field criteria to descale iron sulfide scale and stimulated well injectivity. The deployment of the FeS dissolver can result in 67 % increase in overall well injection rate compared to pre-chemical descaling rate. Other tangible benefits to this chemical include avoidance of rig workover operations to pull and replace downhole tubing in cases where mechanical descaling was not successful in restoring wellbore access. The new chemical allows for conducting safer descaling operation by reducing risks associated with reproduction of hydrogen sulfide, formation damage from non-friendly chemicals, and downhole equipment damage by corrosion. The chemical also has the ability to dissolve carbonates for near wellbore cleanup. The dissolver has a 70 % enhanced dissolving ability comparing to 15% HCl.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"325 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122244008","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"CO2 Plume Detection Using Ras, Temperature and Noise Tools in A CO2 WAG Reservoir","authors":"Arit Igogo, A. Hutajulu, Yassin Farouk Mohamed Sallam, Sara Hasrat Khan, Yatindra Bhushan, Mona Yousif Al Ali, R. AlSeiari, Mohamed Abdulhameed Aidroos Alwahedi, Shareefa Ahmed Al Hammadi, Aamna Al Teneji","doi":"10.2118/211685-ms","DOIUrl":"https://doi.org/10.2118/211685-ms","url":null,"abstract":"\u0000 In alignment with most company's vision to reduce greenhouse effects by expanding CO2 carbon capture and utilization for oil fields, CO2 gas is injected into the reservoir to enhance oil displacement and maintain reservoir pressure. Since CO2 gas is miscible in the oil, the gas flood front is not piston-like; the gas is slowly absorbed by the oil changing the oil properties. Detection of the CO2 plume is necessary to monitor CO2/ injected water/ oil distribution (at and away from the well) and to track the effectiveness of the complicated CO2 WAG injection process in terms of improved sweep efficiency.\u0000 Monitoring CO2 flood front movement requires a logging measurement that can distinguish oil from CO2 in the formation. This measurement must have a sufficiently large dynamic range for the change from no CO2 to a high CO2 saturation to be distinguished within measurement error. This paper highlights the utilization and integration of Reservoir Analysis System (RAS) and Noise tools in CO2 plume detection. It also highlights some of the limitations of the RAS tool in high water transition zone in CO2 WAG environment.\u0000 As the oil is push away from the injection well, the flood front will be characterized by oil having varying amounts of miscible CO2 gas dissolved in it. The rate and composition of the injection gas determines how much of the oil that will expand. The density of the oil may not change much (since the oil density is close to the CO2 gas density) but the hydrogen density of the oil will decrease considerably as is the case for CO2. Another factor that controls the CO2 plume movement is the stratigraphy of the heterogeneous carbonate reservoir – where the coarsening upwards trend of the facies associations of High Stand Systems Tract (HST) coupled with pervasive cementation, creates non-uniform movement of CO2 plume vertically and spatially.\u0000 Logging results shows Neutron porosity (PHIRN) and PNC near/far capture ratio are the preferred log measurement curves because they have the most sensitivity to the large decrease in hydrogen index when CO2 replaces oil or is dissolve in oil. Other curves like Ratio of Near to Long at Burst (RLNB), Long Inelastic Rate Sigma (LIRS), temperature and noise logs also play significant roles in CO2 plume indications.\u0000 The outcome of this study has helped understand the vertical and lateral extent of the CO2 WAG flood front, estimate saturations, evaluate the well integrity, and locate un-swept zones. Additionally, RAS data is hard data used as calibration (blind test) to check the robustness of the dynamic model.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121627427","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Unveiling the Value of Data - An End-to-End Data Analytics System at Scale for Logging Operations","authors":"V. Torlov, M. Kanfar, Sachit Saumya, Oscar Gill","doi":"10.2118/211833-ms","DOIUrl":"https://doi.org/10.2118/211833-ms","url":null,"abstract":"\u0000 This paper presents a summary of a Wireline Logging Operations Analytics System and a patented workflow that has brought a paradigm shift to a logging operations assessment. The aim was to provide a holistic insight into logging operations and enable optimization of time, operational capability, resources, and reduction in carbon footprint. The described digital transformation initiative led to the design and implementation of an end-to-end data analytics system at scale.\u0000 The process started in 2020 with the implementation of events tracking software that enabled Logging Engineers to create a comprehensive dataset containing detailed labelled wireline logging activities record with an extensive set of job metadata. The records comprise temporal depth, surface, and downhole tension data, drilling parameters log, detailed job parameters, downhole instrumentation, and time-mapped activities which constitutes a comprehensive hierarchical events tree. The operational events are either tracked during the job or identified based on a stack of raw log signatures and are captured through an interactive graphical process using a dedicated interface.\u0000 To leverage the big data, sets of immersive analytics dashboards was designed to address different parties’ inquiries. The system integrates data from multiple sources and includes extensive ETL (extract, transform & load) routines. Multiple queries and further computations were applied to unveil the full value of data within the Well Logging domain including operating efficiency, incidents records, hole conditions tracking, sustainability etc. Domain knowledge paired with statistical and machine learning analyses allowed ranking performance affecting factors and establishing the variable operational performance metrics. Using the established baselines, activities duration is compared to a calculated reference, and is summarized over the attribute of interest, e.g. logging company or a crew, area, rig, conveyance, category or distinct activity, job type, time etc. Periodic summary review allows tracking the performance of Logging company in respect to established metrics by a variety of parameters. Some Logging companies have introduced Engineer's scorecard that provides performance insights and input to a competency assessment. The implemented approach moves away from a rudimentary efficiency assessment (binary productive vs non-productive time). The implemented system is a pioneer in data analytics driven solution at scale for logging operations. According to the Logging companies, it is the first exhaustive recording of logging activities in the world, that can be used to evaluate operational performance, identify, prescribe, and track the improvements.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"13 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132311195","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Application of 4D Geomechanical Modelling for Fault Critical Re-Active Stress Evaluation in Underground Gas Storage","authors":"Dong Chen, Wei Zhou, Ji Luo, Zhaoting Huang, Hanbing Xu, Ying Fu, Ronghong Cheng, Liming Lian, Q. Jin, Xia Qiao, Mimi Wu, Xiao Yang, Xingning Huang","doi":"10.2118/211019-ms","DOIUrl":"https://doi.org/10.2118/211019-ms","url":null,"abstract":"\u0000 Fault stability is the risk of reactivation under dynamic stress conditions. The reactivation of faults in the oilfield is mainly caused by the increase of fluid pressure in the reservoir zone, with the quantitative evaluation index of the critical reservoir pressure required for fault reactivation under the current pore pressure condition. When the formation pore pressure reaches the critical stress, the corresponding fault part will be in a critical stress state. The slippage of the critical stress fault tends to cause fluids leakage. Therefore, the study of fault stability is of great significance to oilfield production; In order to guarantee national natural gas peak regulation and supply, the YH underground gas storage (UGS) has been proposed and is carried out with the project of expanding storage capacity and increasing production. The operator hopes to effectively guide the optimization of the limit operation pressure and ensure its long-term safe operation. It is urgently required to carry out fault stability evaluation for the YH underground gas storage. The operator plans to find out the conditions for the activation of the faults, with studies about the stability of the fault under the impact of mining and the impact of the system parameters on the stability of the fault. The results suggest that: whether the fault is in a stable or active state depends on the magnitude relationship between the apparent friction factor (k1) and the fault friction factor (k). When k1 < k, the fault will be in a self-locking state. However, when k1 ≥ k, the fault is in a reactive state. The apparent friction factor reflects the stress risk level of the fault under the collective impact of the in situ stress (including σ1 and σ3), the cohesion of the fault plane (c) and fluid pressure of fault (pi). Higher k1 indicates higher tendency of fault re-activation. k is a quantity factor determined by the friction angle (φ) within the fault. The larger friction angle of fault indicates higher friction factor and the more stable state. The system parameters (includingφ, c, pi, σ1 and σ3) will affect the stability of the fault after the change of initial stress conditions: the smaller cohesion of the fault plane and greater fracture fluid pressure indicate the fault will be easier to reactivate. This paper established the 4D dynamic geomechanical model of the YH underground gas storage and took the fault stability as the judgement basis to analyze the in-situ stress characteristics of different faults. The research results could be used to evaluate the UGS operation safety quantitatively under the impact of the dynamic stress conditions, which will provide technical guidance for optimizing the operation plan of the UGS.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"16 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133937164","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"OPEX Optimisation for Un-Piggable Vent Line/Low Flow Pipeline Inspection via Self-Propelling Robotic ILI Tool","authors":"Mohamed Ali Abdullah, Aishah Mastura Supian, M. N. Ahmad, M. N. M Ali Napiah, Ahmad Sirwan Mat Tuselim, Muzdalifah Zakaria, Hendra Luthfi Hassan, Mohamed Ridzuan Mohamed Abd Salam, Gurin Denis, Lebedev Mikhail, Fertikova Elena, Romanovich Vitaly","doi":"10.2118/211184-ms","DOIUrl":"https://doi.org/10.2118/211184-ms","url":null,"abstract":"\u0000 This paper is to share the development of Self-Propelling Robotic In-Line Inspection technology that PETRONAS embark as OPEX optimization for un-piggable pipeline. Lack of conventional inspection methods to inspect un-piggable pipelines such as vent pipelines without pig traps facility and low flow pipelines, has prompted PETRONAS to embark on technology development journey for Self-Propelling Robotic ILI.\u0000 The development of the Self-Propelling Robotic In-Line technology consists enhancement of robotic tethered crawler tool to a wireless robotic tool, testing and validation using actual full scale fabrication test loop. Fabricated test loop includes horizontal and vertical section with bends of 1.5D to simulate the inspection tool travel as per actual site condition representing vent line.\u0000 The enhancement consists of wireless connection range, optimum speed and distance, movement of slippery surface which grease was applied on the vertical section and emergency extraction of inspection robot.\u0000 Robotic ILI qualification test which was successfully met PETRONAS requirement based on full scale factory acceptance test. The test was focused and able to meet below success criteria: -\u0000 Robotic ILI tool able to self-propel on vertical test spool. Robotic ILI tool able to move with wireless connection for the intended travel length. Emergency retrieval tool procedure and mechanism in the event of faulty robotic ILI or loss of connection. Sensor detection capability at POD 90% and POI 80%.\u0000 Based on the evaluated technology, Robotic ILI solution is feasible in ascertaining the un-piggable pipeline integrity and recommended solution to tackle high operational costs that upstream operators face when inspecting their pipelines using current available methods. Deployment of this technology is estimated to provide up to 30% OPEX optimization. The technology has been evaluated to be technically ready and tested which currently in the stage of pilot testing.\u0000 Current approach to inspect un-piggable vent or low flow pipeline is Crawler ILI type technology which propelled by umbilical cable whereby the pipeline requires to be in shutdown mode. While inspection using Self-Propelling Robotic ILI can be applied for un-piggable pipeline i.e. low flow pipeline and vent line with short duration or no requirement of shutdown.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"19 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134182703","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}