Day 1 Mon, October 17, 2022最新文献

{"title":"Understand the Unconventional Reservoir Heterogeneity via Far-Field Sonic Imaging and Chemical Tracer Evaluations: A Case Study from Wulalike Shale Gas Exploration in Ordos Basin","authors":"Ziyue Cui, Sheng-li Xi, Zhanrong Ma, Gang Wang, Ning Fu, Gaohong Yu, Lei Zhao, Yuan Liu, Yanyan Chen, Yuanhua Li, C. Qu, Qing Wang, Zeren Ma, Joël Le Calvez","doi":"10.2118/210621-ms","DOIUrl":"https://doi.org/10.2118/210621-ms","url":null,"abstract":"\u0000 One of the most challenging aspects of unconventional reservoirs is their heterogeneity. Natural fissures, faults, or laminations, which are the main causes for the heterogeneity, are either measured only on the wellbore or not measured at all. In our recent work on a Wulalike shale gas exploration well, we visualized the heterogeneity with three-dimensional far-field sonic imaging technology during logging, and we evaluated the uneven production profile in the horizontal laterals with chemical tracer during production test. The result of the two methods is highly consistent, which indicated the far-field sonic imaging technology is an effective way to understand reservoir heterogeneity, particularly for unconventional resources.\u0000 High-resolution image logging and three-dimensional far-field sonic imaging technology were introduced to a newly drilled horizontal well in Wulalike Shale gas. Multilevel multi-azimuthal acoustic waveforms were acquired with long enough record length to capture the reflections from the mentioned microscopic features. The innovative ray tracing inversion and three-dimensional slowness-time coherence (3D STC) methods were utilized on the filtered waveform to quantitatively determine the true dip and azimuth as well as the distance of the features from the wellbore. And as a result, only four depth intervals were identified by 3D far-field sonic where fractures extended away from the wellbore to far field. The distance of the fractures from the wellbore was in a range of 8 to 28 m.\u0000 Chemical tracers were deployed during the fracturing and completion phase to evaluate the new findings from the logging. The uneven production profile from the chemical tracer indicated that 4 out of the 17 stages were the major contributors for more than half of the gas production. Each lateral for those four stages were accompanied with the observation of fissure or lamination signature from the far-field sonic images and resistivity image logging data. This showed that this sonic imaging technology was effective to link the reservoir heterogeneity to its production, making it a valuable tool for the future unconventional reservoir evaluations.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"77 1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134021836","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":"Effective Well Engineering Approach for Completion Intervention, Stimulation and Flow Measurement to Enhance Efficiency and Production Performance","authors":"Ayman Alharbi, AbdulMuqtadir Khan, Hashem Alobaid, S. Ashby, D. Ahmed","doi":"10.2118/210685-ms","DOIUrl":"https://doi.org/10.2118/210685-ms","url":null,"abstract":"\u0000 Well completion practices in high-temperature, high-pressure carbonates are challenging especially for long lateral horizontal wells intended for fracturing applications. An integrated approach involving intervention and fracturing design and reliable post-fracturing flow measurements is very critical to optimize the well performance.\u0000 After initial intervention complexities due to wellbore accessibility in a 6,250-ft cemented lateral initially planned with 13 fracturing stages resulting in the loss of many operational days, a revamped engineering workflow was planned for Well-A. As a first step, Coiled Tubing (CT) was used for abrasive jetting perforations, cleanout, and acid squeeze functionalities with a novel bottomhole assembly (BHA). The BHA was equipped with a real-time telemetry to optimize intervention to a single run. Having real-time bottomhole parameters helped in perforating the desired zones accurately and enhanced the injectivity by creating cleaner perforation tunnels.\u0000 Stages were reduced to five with an optimized perforation design based on rock typing approach, and short clusters were designed to divert the fracture fluids effectively using multimodal particulate diversion. Each fracturing stage was isolated with a mechanical plug. A novel high-frequency pressure monitoring technique that analyzes fluid entry points from water hammers was utilized during the fracturing treatments to analyze on-the-fly diversion efficiency and optimize further treatments.\u0000 A multiphase flowmeter was utilized to enhance milling and flowback to minimize losses and manage the choke schedule based on actual well performance leading to better fracture cleanup and recovery. The production performance of Well-A was compared with two offset horizontal wells drilled azimuthally parallel, intersecting the same carbonate sublayer. The post-fracturing absolute production enhancement analysis showed 11 to 15% improvement, and productivity index (PI) improvement was 40 to 63% when normalized by stage count. The effective integration of multiple technologies was applied successfully on the candidate well, yielding enhanced operational efficiency with optimized production performance.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116638478","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":"Success Story of Novel Digital Transformation Tool for Offshore Surface Facilities Bottlenecking Analysis","authors":"Pimpisa Pechvijitra, Manisa Sangwattanachai, N. Atibodhi, Supha-Kitti Dhadachaipathomphong, Janejira Srichaitumrong, Jirat Juengsiripitak, Ratipat Techasuwanna, Supaluck Watanapanich, Kantkanit Watanakun","doi":"10.2118/210727-ms","DOIUrl":"https://doi.org/10.2118/210727-ms","url":null,"abstract":"\u0000 With technology disruption and the increasing trend in big data, it is crucial for offshore gas production fields to transform process performance monitoring practice from manually monitoring on monthly basis by site process engineers to real-time monitoring with a predictive model. Hence, Surface Facilities Bottlenecking Analysis (SBA) initiative has been raised to provide production uplift through continuous identifying factors that constrain production, and to gain insights through predictive capability of automatic process performance monitoring on key production facilities.\u0000 In SBA, the advanced process modelling programs, including process design and simulation and advanced process monitoring are used to predict the capacity and the performance outcome of surface production facilities. An online dashboard with key features to visualize the live production rate, the current overall hydrocarbon field potential, and the future production profile against the surface facilities capacity is developed. With this function, the bottleneck in any period of time can be instantly identified and the notification is distributed to related parties to be aware of and arrange plan / activity if de-bottlenecking is required. Furthermore, the online dashboard provides the real-time performance monitoring of key surface production facilities, such as mercury removal absorbent unit, heat exchanger, gas/condensate/produced water filter, and de-oiling/de-sander hydrocyclone. With this, more precise maintenance intervention time prediction as per actual equipment performance based is achieved.\u0000 By utilizing the novel digital transformation tool for SBA, the presence of the tailored monitoring system leads to the enhancement of facility equipment reliability through examining live data with operating window and alignment with asset performance management through predictive performance capability. Main surface facilities, selected to be monitored under SBA scope, are as follows:\u0000 Mercury removal absorbent unit (MRU): the prediction of the absorbent bed change-out time, based on the predicted bed saturation condition, is achieved. Dehydration unit (Memguard): the dew point is monitored to evaluate the unit performance. Heat exchanger and waste heat recovery unit (WHRU): the software is able to predict the chemical/mechanical cleaning time, based on the actual tube fouling condition and the maximum acceptable flow rate that the equipment can handle to achieve the required outlet temperature or heat duty. Gas/condensate/produced water filter: the predictive trend for the filter change-out time, based on the pressure drop trend and the maximum flow through the filter at the maximum differential pressure, is provided. De-oiling/de-sander hydrocyclone: the predictive model for the internal cleaning and the replacement of the liners, based on the deviation of the actual versus design performance curve, is displayed on the online dashboard.\u0000 Apart from monitoring and pred","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124985270","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":"Novel Application of AI: Harnessing Tacit Knowledge for LNG Plant Start-Up","authors":"Kian Seng Lee, Xin Wei Yeap, Elaine Synn Yie Khoo, Yong Xian Lee, Shiuan Yong, Yi Han Hiew, Hafiz Maamor, Saifuddin Zulkaple","doi":"10.2118/210674-ms","DOIUrl":"https://doi.org/10.2118/210674-ms","url":null,"abstract":"\u0000 To capture the invaluable tacit knowledge from skilled operators and leverage on insights generated from over two decades of plant operation data, an AI-driven live advisory was developed to provide operators with real-time parameters control advisory during start-up, in response to actual process and equipment conditions. The solution had been deployed to ten start-ups in Malaysia LNG, successfully achieving 44% reduction in duration and 17% reduction in carbon emission from reduced gas usage. The shorter start-up duration translated into significant value creation from production opportunity, yielding an impressive return on investment of 35, in just 15 months. Furthermore, six of the start-ups also emerged as the top executions when benchmarked against all historical occurrences in the past two decades, demonstrating its ability to enable consistent and optimised start-ups.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"12 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127902009","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":"An Integrated Approach to Asset Management: Understanding Inflow Control Device Performance and Managing Integrity Risk in a Well with High Gas/Oil Ratio","authors":"T. Mccarthy, Hayley Sophia Pedler, Ken Ichihashi, Nicole Lashley, Z. Dholkawala","doi":"10.2118/210762-ms","DOIUrl":"https://doi.org/10.2118/210762-ms","url":null,"abstract":"\u0000 \u0000 \u0000 The Laverda Field is an offshore waterflooded field developed with two long horizontal producers targeting two stacked high quality sandstone units. The oil producer LAV02ST2 is completed with sand screens and Inflow Control Devices (ICDs). Elevated Gas Oil Ratios (GORs) were experienced during start-up, which indicated free gas production downhole, raising concerns over ICD erosion and sand production. While the ICDs have defined operating limits in the presence of single-phase flow, the safe operating range in multi-phase flow conditions was highly uncertain. Given the significant risk of well failure due to erosion, additional bean up was halted pending studies to understand and quantify the erosion risk.\u0000 Erosion risk was influenced by:\u0000 the distribution of gas along the well (concentrated vs dispersed inflow), the presence of an open annulus and associated erosion risk due to solids production, and tolerance of the ICDs to higher velocities under three-phase flow.\u0000 \u0000 \u0000 \u0000 Collaboration between subsurface and completions disciplines was required to understand the source of the gas and assess the risk to completions. Initially, production trends were analysed in conjunction with a review of geological data and numerical simulation insights to identify likely sources of gas and which areas within the well were more susceptible to gas exposure.\u0000 Near-wellbore modelling using NETool® and GAP was undertaken to understand the range of feasible gas inflow scenarios and eliminate scenarios inconsistent with observed production data. The most likely scenario was then used to establish the relationship between total well rate and peak velocities in the ICDs, for a worse-case erosion outcome.\u0000 To understand the risk of ICD erosion under multi-phase flow and potential for loss of well integrity, Computational Fluid Dynamics (CFD) modelling was conducted on a range of expected production scenarios to establish safe operating limits. Both, ICD slot erosion and housing erosion behaviour was investigated, as a function of peak ICD gas rate/velocity, well liquid rate and well GOR.\u0000 \u0000 \u0000 \u0000 The CFD study helped to establish a relationship between erosion rate and total downhole rate at reservoir conditions for various production scenarios, thus allowing calculation of erosion over the course of field life. A revised safe operating envelope was recommended for the oil producer in multi-phase conditions that allowed the production rate to be doubled without compromising well integrity.\u0000 \u0000 \u0000 \u0000 Traditionally, industry physical erosion testing of the ICDs by the vendor is restricted to single-phase, liquid conditions only. Successfully benchmarking the CFD model to the single-phase physical tests allowed quantification of erosion rates in multi-phase flow and establishment of a safe operating envelope over the life of the well.\u0000","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"29 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121432425","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":"Acid Stimulation Campaign in Ghana Offshore Using Riserless Light Well Intervention Vessel","authors":"G. Leo, Simone Borra, Paolo Giovanni Pasquali, Gianluigi Sala, Luca Borri, Davide Flamminio, Donatella Stocchi, Carlo Mastrocola, A. Lazzari, Matteo Tadini, Lorenzo Ferraro, Antonio Fiameni","doi":"10.2118/210666-ms","DOIUrl":"https://doi.org/10.2118/210666-ms","url":null,"abstract":"\u0000 Scope of this paper is to describe the acid stimulation campaigns carried out in Ghana Offshore field between 2019 and 2020. The campaigns were carried out with a Light Well Intervention (LWI) vessel using different subsea equipment which allowed to safely perform the stimulation operation connecting the vessel to the X-tree production facility.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115318745","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":"Impact of Hydrogen Sulfide Scavenger Residuals on the Fluorescence Behaviour of OiW Discharges from Gas-Condensate Production","authors":"M. Lehmann, G. Vamvounis, Sarah B. Bloom, Jake Prout, Henry Gordon-Wright, Sambit Das","doi":"10.2118/210760-ms","DOIUrl":"https://doi.org/10.2118/210760-ms","url":null,"abstract":"\u0000 The oil-in-water (OiW) contaminants in produced water discharges arising from offshore oil and gas production systems are required by global regulatory bodies to be monitored in order to limit the environmental impacts of such releases. The level of these contaminants is commonly measured using online analyzers that utilize UV fluorescence to target the luminescent properties of OiW components.\u0000 It is known that the nature and variability of the fluorophores in the OiW fractions may influence the response of these type of analyzers. In particular these readings can also be affected by chemical residuals used in oil and gas treatment, that may also be present in the produced water. This study reports on the impact of the reaction products of a monoethanolamine based hydrogen sulfide scavenger, used in gas treatment to remove hydrogen sulfide (H2S), on the fluorescence behavior of OiW discharges, and its implications on the OiW reporting levels that may be expected from deep-UV and near-UV based analyzers.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127683746","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":"Smart MIMO-OFDM Wireless Communication Frameworks for Subsurface Wireless Sensor","authors":"Klemens Katterbauer, Abdallah Al Shehri","doi":"10.2118/210750-ms","DOIUrl":"https://doi.org/10.2118/210750-ms","url":null,"abstract":"\u0000 Wireless communication in subsurface wells and reservoir has been a major challenge in ensuring robust data transmission, and reliable communication between the sensors. Challenges from the multiple reflection as well as other external factors, makes subsurface communication a unique challenge for modern communication algorithms. While multiple-Input, multiple-output orthogonal frequency division multiplexing (MIMO-OFDM) communication has been extensively implemented in wireless communication for signal processing, unique challenges arise in subsurface reservoirs caused by unknown formation properties and fluid movements.\u0000 We present a new smart MIMO-OFDM algorithm for wireless communication in subsurface reservoirs. The new algorithm integrates both MIMO and OFDM into a deep learning framework. It optimizes the communication quality as well as reliability of the communication between the various subsurface wireless devices. The joint integration and smart adjustment leverages the power of both algorithms simultaneously, and allows significantly improved communication robustness between the wireless devices.\u0000 We tested the smart MIMO-OFDM on a synthetic carbonate reservoir formation with multiple wireless sensors and wireless appliances. Fracture Robots (FracBots, about 5 mm in size) technology will be used to sense key reservoir parameters (e.g., temperature, pressure, pH and other chemical parameters). The technology is comprised of a wireless microsensor network for mapping and monitoring fracture channels in conventional and unconventional reservoirs. The system establishes wireless network connectivity via magnetic induction (MI)-based communication, since it exhibits highly reliable and constant channel conditions with sufficiently communication range inside an oil reservoir environment. The results exhibited strong performance of the wireless communication, hence providing reliable and robust subsurface wireless communication.\u0000 The novel framework presents a vital component in enhancing subsurface wireless communication and achieve robust data transfer. The results outline the opportunity for wireless communication to become a critical component for subsurface communication.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134421839","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":"Integration of Mineralogy, Petrophysics, Geochemistry and Geomechanics to Evaluate Unconventional Shale Resources","authors":"Gang Hui, F. Gu, Zhangxin Chen","doi":"10.2118/210642-ms","DOIUrl":"https://doi.org/10.2118/210642-ms","url":null,"abstract":"\u0000 It is not entirely understood how related geological parameters vary during the thermal maturation and development of shale resources and controlling factors of shale productivity. Here, a detailed examination of mineralogy, geochemistry, petrophysics, and geomechanics-related data is conducted to explore the productivity of the Fox Creek, Alberta shale play. Experiments using X-Ray Diffraction, Tight Rock Analysis, Rock-Eval Pyrolysis, and Triaxial Compression are conducted to characterize the mineralogy, petrophysics, geochemistry, and geomechanics of the region under study. Multiple Linear Regression (MLR) is used to quantify the relationship between shale output productivity and reservoir input parameters. Using 300 core samples from 15 wells targeting the Duvernay shale, the key governing characteristics of shale potential were then examined. The Duvernay shale is dominated by quartz, clay, and calcite, according to X-Ray Diffraction measurements. Tight Rock Analysis indicates that the effective porosity of the Duvernay shale ranges from 1.56% to 6.11%, with an average value of 3.97 %, while the core permeability ranges from 0.25 to 345.5 nD, with an average value of 127.2nD. The total organic carbon (TOC) content ranged from 2.32 to 5.0 %, with an average of 3.86 %, according to Rock-Eval Pyrolysis testing. The majority of the Duvernay shale near the Fox Creek region (i.e., Fox Creek shale) was deposited in an oxygen-depleted maritime environment, whereas the Duvernay shale was in the gas generation window. The MLR technique determines the elements controlling shale productivity, including the production index, gas saturation, clay content, porosity, total organic carbon, brittleness index, and brittle mineral content as input parameters in decreasing order. Based on the MLR prediction model, the expected 12-month shale gas production per stage corresponds well with the actual value. This strategy can guide the future selection of horizontal well drilling sites and lead to the efficient and profitable development of shale resources.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"47 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131603091","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":"A Case Study of Design and Installation of Upper Completion System for a Deepwater Gas Field in South China Sea","authors":"Yi Huang, Wen-bo Meng, Donglei Jiang, Xue Peng Wang, Haiquan Chen, Jianbo Su, Nigel Ruescher, Fei Xu, H. Diao, Heng Wang, Tan Xiao, Ying Hao Wang, Yi Yu","doi":"10.2118/210735-ms","DOIUrl":"https://doi.org/10.2118/210735-ms","url":null,"abstract":"\u0000 The urgent demand to replace the rapidly declining conventional reserves is driving China's operators to accelerate the development of deepwater reservoirs. SHENHAI Project is the first deepwater project operated by CNOOC China Ltd., locates in water of 1220m to 1546m in South China Sea.\u0000 Deepwater completions differentiate themselves not only by unique technical challenges, but also by their high cost, risk, and long project cycles. A sound project management process is essential to ensure flawless execution. By reviewing the key steps of the SHENHAI deepwater completion campaign, such as upper completion design, critical equipment selection, interface management, workshop preparation, and final project execution, lessons learnt, etc., this paper provides both a job cycle of completion design-to-execution and a methodology to manage a complex project by addressing the challenges inherent in the deepwater completion process.\u0000 As a result, the well completion campaign was completed ahead of schedule. A total of 11 deepwater wet-tree wells were successfully delivered as designed including two dual-zone hydraulic controlled intelligent wells. The upper completion design has been proven to be safe and reliable with first applications of several critical upper completion tools in the region, such as Nitrogen-Charged Surface Controlled Sub-surface Safety valve (SCSSV), Hydrostatic-Setting production packer and quartz-based permanent downhole pressure gauge.\u0000 This success demonstrates the completion design and practices are applicable for this deepwater project and can be extended to further offset deepwater projects in this area. This paper describes case details of successful upper completions of SHENHAI project aiming to provide information and experiences for engineers who may face the similar challenges.","PeriodicalId":151564,"journal":{"name":"Day 1 Mon, October 17, 2022","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121239101","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}