Day 4 Fri, March 25, 2022最新文献

{"title":"Internal Sound Pressure Level Estimation Considering Design Through Computational Aeroacoustics","authors":"Olivier Macchion, Leszek Lukasz Stachyra, H. Morand","doi":"10.4043/31614-ms","DOIUrl":"https://doi.org/10.4043/31614-ms","url":null,"abstract":"\u0000 Subsea chokes differ from the standard choke designs that can be found in for example the IEC 60534-8-3 standard, due to their geometry but also due to the environment. Contrary to topside chokes where monitoring for sound and vibration can be carried out in a relatively straightforward manner, noise and vibration monitoring is not easily executed subsea, which means that the estimate of the generated noise needs to be calculated, or extrapolated in some way from lab data.\u0000 Computational methods to validate designs often provide an alternative method to physical validation testing when size or recreating particular environments are impractical. However, to be able to use computational analysis for this purpose, it is essential to ensure that a sound and benchmarked methodology is applied. This paper discusses an optimized methodology that combines Computational Aeroacoustics and IEC 60534-8-3 for the estimation of the internal sound pressure level (SPL) generated by choke valves.\u0000 Three broad types of tools (all broadband models) are available to estimate hydrodynamic induced SPL, namely: 1) one-way coupled Computational Fluid Dynamics (CFD), 2) acoustic solvers, 3) two-way coupled CFD and acoustic solvers, also called Computational Aeroacoustics (CAA) solvers. Out of these three types, CAA accounts for both the geometry of the equipment generating the internal SPL, but also models the complex interaction between hydrodynamics and acoustics, including tones generated by cavities. While the advantage in terms of output is significant, CAA comes at a large computational cost due to the requirements in space and time discretization that must be satisfied to properly resolve the frequency range from 12.5 Hz to 20 kHz.\u0000 The CAA methodology presented in this paper is validated against two sets of data obtained in laboratory conditions for Mach numbers ranging from 0.08 to 0.36. Then the same methodology is applied to the specific design of the choke valve. The obtained outputs in form of an acoustical efficiency and peak frequency are then used to tune the IEC 60534-8-3 method, this allows accurate estimation of internal SPL for the given geometry. The combination of the CAA and IEC enables efficient consideration of the actual geometry of the choke with regards to internal SPL prediction against a wider range of conditions without requiring a larger set CAA calculations.\u0000 The methodology presented in this paper can be applied to similar problems ensuring faster and more accurate results compared to the other available industry practices like physical testing.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"83 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86078026","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":"Treatment and Prevention of Stuck Pipe Based on Artificial Neural Networks Analysis","authors":"Qi Zhu","doi":"10.4043/31693-ms","DOIUrl":"https://doi.org/10.4043/31693-ms","url":null,"abstract":"\u0000 Oil and gas drilling is a field practice with risks and uncertainties. Uncertainty and ambiguity of formation conditions often cause downhole accidents such as borehole wall instability, stuck drilling, blowout, etc., and also pose a threat to drilling safety.Due to the incorrect understanding of the objective environment and the wrong decision of subjective consciousness; it caused complex underground conditions and serious accidents.\u0000 Collapse stuck is the worst kind of accident in stuck stuck. The procedures to deal with this kind of accident are the most complicated, the most time-consuming, the most risky, and even the whole or part of the wellbore may be scrapped, so we should try our best to avoid this accident during the drilling process.Artificial Neural Networks (ANNs for short) is a mathematical model of algorithms that imitate the behavioral characteristics of animal neural networks and perform distributed parallel information processing.\u0000 This kind of network depends on the complexity of the system and adjusts the interconnection relationship between a large numbers of internal nodes to achieve the purpose of processing information, and has the ability of self-learning and self-adaptation.\u0000 This paper analyzes the causes of collapse stuck, the mechanical mechanism of drilling fluid wettability on the stability of mud shale formation wall.A surface wetting reversal agent added to the drilling fluid system was used to change the wettability of the shale surface.The mechanism analysis and research results of changing the wettability to change the mechanical properties of the shale fracture surface were applied to the actual production of the collapsed drilling rig.Through the change of drilling parameters, the risk of stuck drilling is predicted in advance, the drilling speed is increased, the drilling time loss caused by stuck drilling is reduced, and the drilling cycle and cost are saved.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84083796","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":"Minimising Downtime During Multiple Valves Change Outs on Critical Gas Export Pipelines","authors":"Raja Zahirudin Raja Ismail, Wan Ahmad Izuddin Wan Dagang, Rolf Gunnar Lie","doi":"10.4043/31367-ms","DOIUrl":"https://doi.org/10.4043/31367-ms","url":null,"abstract":"\u0000 To enable the safe replacement of five valves whose passing rates exceeded allowable limits, PETRONAS Carigali Sdn Bhd (PCSB) in 2017 used a three-module high pressure isolation tool (HPIT) to isolate one 24-inch and two 32-inch critical gas export pipelines at ANDR-A in the Angsi field in offshore Peninsular Malaysia. The SmartPlug® tool provided a double block and monitor (DBM) isolation without requiring depressurization or bleeding down the entire pipeline, which avoided prolonged shutdown. Because the three pipelines shared a common header at the ANDR-A topside, they required simultaneous isolation. Although HPIT had been deployed on main gas export pipelines several times before in Malaysia, this was the first time three isolations were required to be executed at the same time on the same platform during a single shutdown campaign. This Case Study describes the steps taken from planning, site visit and engineering to the safe and successful execution of the isolations.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84726092","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":"Guidance for Design and Operation of Pump Rooms Following the Explosion on the FPSO Cidade de São Mateus","authors":"M. Duddy, A. Ronza, Noorhafizal Zakariah","doi":"10.4043/31639-ms","DOIUrl":"https://doi.org/10.4043/31639-ms","url":null,"abstract":"\u0000 On the 11th of February 2015 a pump room explosion on the Floating Production Storage and Offloading (FPSO) Cidade de São Mateus killed nine persons, injured twenty-six more and crippled the unit, requiring that it be removed to a yard to effect repairs. In 2020 the FPSO Owner confirmed that the FPSO Charter and the Services Agreements with the respective Oil and Gas Company had reached their final terms and the unit remained in lay-up in Singapore.\u0000 Seven years on from this event, although the causes leading up to the incident are well understood within some sections of the oil and gas industry, along with the availability of various high-quality publications on the subject, there remains no consolidated guidance from Classification Societies, regulatory authorities, insurers nor industry advisory groups on how to prevent a reoccurrence of a similar event. Indeed, some FSO/FPSO operators have not implemented the required changes within their existing fleet or within their subsequently developed facilities.\u0000 This paper provides a synopsis of the incident onboard the FPSO Cidade de São Mateus (CdSM) and the root causes of the accident. From those findings, it describes the design and operational measures some Floating Storage and Offloading (FSO)/FPSO owner/operators and oil and gas companies have implemented to further reduce the potential risks associated with the use of pump rooms. These measures are subsequently visualised by way of a bow-tie diagram. An overview of current Classification Society rules and regulatory authority requirements relating to pump rooms are shown and discussed. Furthermore, the paper demonstrates some of the flaws that still exist in the engineering and operation of contemporary FSO/FPSO pump rooms. As a continuation from those defects, several FPSO pump room incidents that have occurred after 2015, which could have led to a similar catastrophic pump room explosion to that of CdSM, are explained. Finally, the paper contains a recommended basis for design and operational guidance to owners and operators of FSO/FPSOs with pump rooms.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89437275","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":"Safer Design by Tube Rupture Analysis","authors":"M. Kulkarni, Tongyuan Song","doi":"10.4043/31337-ms","DOIUrl":"https://doi.org/10.4043/31337-ms","url":null,"abstract":"\u0000 When a tube ruptures in a shell and tube heat exchanger, the effect of liquid hammering may induce very high transient pressure on shell side due to the leaked mass from tube side travelling to shell side. This article describes a novel technical approach to adequately translate the volume displacement effect by the leaked mass from tube side onto the shell side holdup volume in the unit. The transient pressure from the liquid hammering effect is then accurately predicted by a first principle simulator, and proper mitigation measures may be identified to meet safety requirement while minimizing capital cost.\u0000 While assuming tube side pressure at tube sheet location remains constant, the mass flow rate profile through the ruptured tube as function of downstream (shell side) local pressure is determined according to industry standards and/or project standards. This profile is then transformed to volumetric flow rate profile displacing shell side hold up volume as function of time in milliseconds time scale. The resulting volumetric profile is then applied to a first principle simulator to predict the transient pressure as a result of liquid hammering effect. The mitigation measure, if any, may be at the same time tested and refined by the simulator.\u0000 The constraints imposed by the project are iteratively evaluated, and adjusted if necessary, to achieve the best reconciliation among factors of capital cost, safety requirement and project schedule etc.\u0000 In this article, a compressor discharge after cooler of double shells, with one stacked on top of another, is used for the discussion. Furthermore, the scope of the model extends to include the surrounding piping, and include any considerable lead line length to the relief device. The details of the exchanger geometry, including internal components such as the baffles, bundle type, nozzle etc. are modeled with adequate resolution. The pressure wave propagation along the path of shell side flow in milliseconds time scale are simulated and the localized peak pressures are reported.\u0000 The high peak pressure necessitates a mitigation measure to be implemented, while maintaining the proposed shell side design pressure to stay for this particular unit. Note that this type of study, for safety concerns, it could result in elevated shell side design pressure, even after considering mitigation measure, leading to major changes to associated supply and return piping, resulting in cost and schedule delays.\u0000 The technical approach illustrated in this article describes the work flow to transform the mapping of mass flow rate as a function of pressure to volumetric flow rate as a function of time in milliseconds time scale, a technique considered as the first time to be introduced into the practice. The approach increases the fidelity of the study greatly, resulting in reduced capital cost as much as possible, while largely mitigating safety concerns.\u0000 The approach also affords us to test multiple configurations o","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"386 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80774548","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":"Assessment of Machine Learning Techniques for Real-Time Prediction of Equivalent Circulating Density","authors":"Vishnu Roy, Anurag Pandey, Anika Saxena, Shivanjali Sharma","doi":"10.4043/31523-ms","DOIUrl":"https://doi.org/10.4043/31523-ms","url":null,"abstract":"\u0000 The equivalent circulating density (ECD) is crucial in avoiding fluid losses or kicks while drilling. It's more critical in wells where the pore pressure gradient is close to the fracture pressure gradient. The conservation of mass and momentum determine the ECD, but this method does not account for other factors like torque, rotating speed, weight on bit, etc. These may affect the ECD directly or indirectly. The aim of this study is a practicality to predict the ECD using various machine learning techniques and to determine their effectiveness.\u0000 The complete drilling dataset of an oil well from Texas was acquired. Over 16000 data points were obtained after the removal of the null values. The data was prepared by scaling it and conducting principal component analysis (PCA). PCA reduced the dimensionality of the dataset while retaining the information. Following this, five different machine learning regression techniques were used to predict the equivalent circulation density, namely, XGBoost, Random Forest, Support Vector Machine, Decision Tree, and Elastic net regression. The performance of these techniques was judged by comparing their R2 scores, mean squared errors (MSE), and root mean squared errors (RMSE).\u0000 The results showed that ECD prediction through all the above machine learning techniques is a vital reality. Random forest regression emerged superior from the different methods used, illustrating the highest R2 score and the lowest MSE and RMSE. Its R2 for our model was 0.992, which is an excellent fit. It was followed by SVM, which had the second-lowest RMSE and an R2 of 0.987, close to the random forest technique. Elastic Net, Decision tree, and XG Boost in the respective order were at the bottom of the pool.\u0000 Machine learning is a powerful tool at our disposal to effectively predict quantities in real-time that directly or indirectly depend on several parameters. It can even be effective when no direct correlation between the quantities is known. Thus, machine learning can significantly enhance our ability to optimize drilling operations by having quicker and more accurate predictions. The work shown in this study, if implemented, can provide the crew more time to respond to situations such as the occurrence of kicks and thus will lead to safer operations.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"139 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78947091","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":"Technology Qualification: FMECA for Mitigating Potential Failure in Subsea Storage System","authors":"Mohd Azizul Hakim Zainal Abidin, A. Suleiman","doi":"10.4043/31608-ms","DOIUrl":"https://doi.org/10.4043/31608-ms","url":null,"abstract":"\u0000 Subsea storage is one of main technology in \"Subsea Factory\" concept that could significantly lower down the field life cycle cost especially in subsea development. An established qualification approach should enable Project Management Team (PMT) to evaluate the technology maturity, aims to reduce significant availability impact during deployment and operational phase. This paper describes the qualification approach adopted to qualify the subsea storage technology to achieve technology readiness level (TRL) 4 as per API 17Q framework, prior to pilot testing at offshore installation. One of important step is to evaluates whether the subsystem and critical components of subsea storage has an impact on Design, Operations and Maintenance. In this context, the evaluation considers the credible failure mode, mechanism, cause, and effect in relation to Risk Priority Number (RPN).\u0000 Failure Mode, Effect and Criticality Analysis (FMECA) has been applied to evaluate the subsystem and critical component. The higher RPN indicates that the susceptible subsystem and critical components require special attention for improvement. The results pointed out that material for both top and bottom centre pipe flanges should have an ability to operate in cyclical loading and suitable for inspection, maintenance, and replacement program.\u0000 These results suggest that recommended method of FMECA can be adopted during TRL assessment. Focus also should be on unlisted components which are not part of this assessment including design adequacy and stringent quality assurance and control management system, operations integrity, and maintenance comprehensiveness.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"83 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88490472","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 Leakage Marine Dispersion Modelling for an Offshore Depleted Gas Field for CO2 Storage","authors":"M. R. Amir Rashidi, Edgar Peter Dabbi, A. I. Azahree, Zainol Affendi Abu Bakar, Dylon Tan Jen Huang, C. Pedersen, Pankaj K. Tiwari, M. T. M Sallehud-Din, M. Shamsudin, M. K. Hamid, R. Tewari, Parimal A. Patil","doi":"10.4043/31447-ms","DOIUrl":"https://doi.org/10.4043/31447-ms","url":null,"abstract":"\u0000 A depleted gas field situated in offshore Sarawak has been identified by PETRONAS as a potential CO2 storage development site. As part of the monitoring program, CO2 seepage risk and impact on the marine environment needs to be investigated and predicted. This study focuses on understanding the environmental risks associated with the potential seepage of CO2 gas at the depleted field within the 140 m water column through methods of numerical modelling. Leakage scenarios involving existing plugged and abandoned (P&A) wells as CO2 leakage pathways were modelled with leakage rates of 6 tonnes/year, representing a realistic rate and 500 tonnes/year which represents a more improbable and conservative scenario. The modelling period covers three representative climatic periods for the prevailing monsoons in the South China Sea (northwest, southwest and inter-monsoon). Simulation results showed that with the lower rate, changes to the seawater acidity within the far field region were negligible or undetectable. Under the high seepage rate, the pH plume footprint was predicted to extend beyond 200 m distance from the source point. However, the probability was estimated to be less than 1% while the vertical extent of the plume was limited up to 2 m above the seabed. For both scenarios, the CO2 gas were predicted to be fully dissolved within 5 m above the seabed. Therefore, it can be concluded that there is relatively low risk of impact at the storage field in terms of potential increase in seawater acidity if CO2 seepage occurs during the storage period.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"95 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86255805","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":"Automation in Cuttings Analysis: Futuristic Preview of Digital Enablement for Geology 101","authors":"C. Shrivastava, K. Bondabou, Mahdi Ammar, Simone Di Santo, Tetsushi Yamada, Sophie Androvandi","doi":"10.4043/31399-ms","DOIUrl":"https://doi.org/10.4043/31399-ms","url":null,"abstract":"\u0000 Analysis of drill-cuttings collected on the rig has always been the most basic, yet most direct means of understanding the subsurface within its own limitations. However, automation enabled by digital transformation of this aspect of mud logging has greatly increased the importance of this data. A futuristic preview is being presented for the repositioning and value showcasing of most basic and widely available data, i.e., cuttings with digital enablement.\u0000 Cost-efficient characterization with lean sample preparation, reducing the adverse environmental imprint to near real-time formation evaluation leading to enhanced well placement and completion design is reshaping the old-school mudlogging with direct detection and quantification of minerals, total organic carbon (TOC), kerogen content and elemental composition; often minimizing the requirement for time-and-cost intensive wireline logging. Labor-intensive sample collection is getting automated, and subjective and descriptive interpretation per experience of mud-logger is giving way to digital, objective interpretation, ready to be integrated with logging-while-drilling data in real-time.\u0000 In addition to the X-Ray Fluorescence & Diffraction; newer technologies like Diffused Reflectance Infrared Fourier Transform Spectroscopy (DRIFTS) are being incorporated in wellsite set-up with reduced footprint on rig and minimized usage of chemicals. Unique automated process can analyze high resolution digital images to deliver plethora of information in minimum time; often augmented with the help of artificial intelligence. A futuristic view with building blocks of the automated interpretation process is presented.\u0000 Examples from different steps needed to achieve automation are provided, from sample preparation to digital analysis through machine learning for a holistic futuristic vision to highlight digital enablement in delivering the well-objectives in cost-efficient and timely manner honoring the changing market dynamics. This foundational cutting analysis (Geology 101) vision would drive further adavnces in this field.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"319 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91470935","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 Cementing Technology for Deepwater Hydrate Layer","authors":"Yu Chen, Y. Li, Yingtao Feng, Hao Zhang, D. Wen, Ce Cui, Youmei Wang, Feng Huang, Min Xiong, Jing Zhao, Wei Wang, Xiong Xiang, M. Song, Hu Zhao, Enlou Fang, Wei Xiao, Jing Ji","doi":"10.4043/31460-ms","DOIUrl":"https://doi.org/10.4043/31460-ms","url":null,"abstract":"\u0000 Methane Hydrates is an ice-like crystalline substance formed by methane and water under high pressure and low temperature environment. Each 1 unit methane hydrates contains about 170 units (converted in standard conditions) of methane gas. The low temperature and high pressure environment in deep water leads to the existence of hydrate layer in the shallow formation, which poses a significant challenge to cementing. The conventional cement slurry systems have limitations when applied in such well condition, since the heat of hydration during cement setting is high and there is a high risk of gas liberation from methane hydrates, easily causing severe well security issues. The low temperature environment, unconsolidated formation and narrow safety window also increased the complexity of the cementing jobs by a high performance requirement of the cement slurry. A low hydration heat cement slurry and an indoor cementing simulation evaluation method were developed in order to ensure effective isolation of the hydrate layer. This paper will describe in detail about the cement slurry development, performance and evaluation process in the lab with a novel method in the industry. This technology was proven as a solution for deep water hydrate layer well cementing, which is a great reference for cementing industry.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"50 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90871622","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}