Day 2 Tue, August 17, 2021最新文献

{"title":"Real-Time Prediction of Choke Health Using Production Data Integrated with AI","authors":"A. Alghamdi, O. Ayoola, Khalid Mulhem, Mutlaq Otaibi, A. Abdulraheem","doi":"10.4043/30981-ms","DOIUrl":"https://doi.org/10.4043/30981-ms","url":null,"abstract":"\u0000 Chokes are an integral part of production systems and are crucial surface equipment that faces rough conditions such as high-pressure drops and erosion due to solids. Predicting choke health is usually achieved by analyzing the relationship of choke size, pressure, and flow rate. In large-scale fields, this process requires extensive-time and effort using the conventional techniques. This paper presents a real-time proactive approach to detect choke wear utilizing production data integrated with AI analytics.\u0000 Flowing parameters data were collected for more than 30 gas wells. These wells are producing gas with slight solids production from a high-pressure high-temperature field. In addition, these wells are equipped with a multi-stage choke system. The approach of determining choke wear relies on training the AI model on a dataset constructed by comparison of the choke valve rate of change with respect to a smoother slope of the production rate. If the rate of change is not within a tolerated range of divergence, an abnormal choke behavior is detected.\u0000 The data set was divided into 70% for training and 30% for testing. Artificial Neural Network (ANN) was trained on data that has the following inputs: gas specific gravity, upstream & downstream pressure and temperature, and choke size. This ANN model achieved a correlation coefficient above 0.9 with an excellent prediction on the data points exhibiting normal or abnormal choke behaviors. Piloting this application on large fields, where manual analysis is often impractical, saves a substantial man-hour and generates significant cost-avoidance. Areas for improvement in such an application depends on equipping the ANN network with long-term production profile prediction abilities, such as water production, and this analysis relies on having an accurate reading from the venturi meters, which is often the case in single-phase flow. The application of this AI-driven analytics provides tremendous improvement for remote offshore production operations surveillance.\u0000 The novel approach presented in this paper capitalizes on the AI analytics for estimating proactively detecting choke health conditions. The advantages of such a model are that it harnesses AI analytics to help operators improve asset integrity and production monitoring compliance. In addition, this approach can be expanded to estimate sand production as choke wear is a strong function of sand production.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"16 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74050392","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":"Lessons Learned from Optimising Sand Control and Management Strategies in a Low Permeability Sandstone Oil Field","authors":"B. Daramola, C. Alinnor","doi":"10.4043/31002-ms","DOIUrl":"https://doi.org/10.4043/31002-ms","url":null,"abstract":"\u0000 This paper presents the lessons learned from optimising the sand control and management strategies of an oil field (Field E) after multiple sanding events and well failures. It presents how the old sand control solution was selected, the failure root causes, and the remediation options considered. The new sand control method, and the performance of two re-drilled wells after two years of production are also presented.\u0000 Field E is a sandstone field with oil and gas-cap gas at initial conditions, and was initially developed with 5 production wells, 2 water injection wells, and 2 gas injection wells. The development wells were drilled from an offshore platform, and completed with stand-alone screens (SAS) in 2013. Oil production commenced in late 2013, and within three years, sand production was observed, and 4 of the 5 oil production wells had failed. The 4 wells were re-drilled in 2017, and the sand control strategy was changed from stand-alone screens to frac-packs.\u0000 Key lessons learned include completing sand strength studies pre-development, avoiding off-the-shelf sand control solutions, and completing sand control design studies based on service contractor capability, fines control, oil production rates, and sand control as key selection factors. Nearby wells should be shut in during infill drilling operations to avoid short circuits, drilling mud losses, completions damage, and well integrity failures.\u0000 It is recommended that the bean up procedures of wells with sanding events are changed to slow bean up to preserve well integrity, oil production, and cash revenues. The asset team should consider installing sliding sleeves or inflow control devices for zonal testing and to choke or close sand production zones if needed. The asset team should also consider installing a test pipeline and a test separator to allocate sand production volumes from each well, clean up new wells, sample the wells for water salinity measurements, and other benefits.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74410799","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":"Brazil Subsea Processing & Boosting Technologies Yard: More Than 20 Years of Lessons Learned","authors":"Marcello Augustus Ramos Roberto, Herbert Prince Koelln, Rodrigo Iunes De Rezende","doi":"10.4043/31032-ms","DOIUrl":"https://doi.org/10.4043/31032-ms","url":null,"abstract":"\u0000 Over the last 20 years Brazil has been the stage where subsea processing and boosting (P&B) technology has supported and pushed the offshore oil and gas production to overcome its challenges and maximize field production and recovery factor.\u0000 Subsea Oil-Water and Gas-Liquid Separation Systems, Multiphase Pumps, Electrical Submersible Pumps, Raw Water Injection Systems, and other innovative, enabler, optimizer or even disruptive technologies have been developing and applying in Brazil's fields to increase the NPV of projects and make feasible long tiebacks scenarios.\u0000 This paper will present a retrospective of the most significant P&B systems developed and deployed in Brazil's fields, their operational experience, lessons learned, the next generation under development to surpass Pre-Salt and brown fields challenges and some initiatives to maximize these technologies applications.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"49 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87569376","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":"LNG Loading Lines High Surge Analysis","authors":"Noor Arnida Abdul Talip, S. A. Abidin, Irfan Ali","doi":"10.4043/31139-ms","DOIUrl":"https://doi.org/10.4043/31139-ms","url":null,"abstract":"\u0000 Proper design of LNG loading lines and verification of emergency shutdown (ESD) interlock systems are critical in ensuring overall safety of the LNG facility. During an emergency, ESD interlock is activated with ESD valves closure initiated simultaneously with all loading pumps trip and the kickback valves open. During the ESD valves closure, the pipeline can be exposed to a risk of high surge pressures exerted onto the wall. A pressure surge or liquid hammering phenomenon in piping systems can be caused by a fluid in motion forced to stop or change direction suddenly (rapid momentum change) and also due to cavitation effect. Cavitation is caused by the formation and instantaneous collapse of vapour bubbles. The collapsing bubbles exert severe localized impact forces that can result in pressure surges. This paper discusses the methodology used to evaluate any potential occurrence of surge and the peak pressure associated with it, using several case studies for analysis. This paper also shares best practice identified from the study to facilitate with safe operations at an LNG loading facility.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"14 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88289578","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 Digital Twin for Real-Time Drilling Hydraulics Simulation Using a Hybrid Approach of Physics and Machine Learning","authors":"P. Varadarajan, Ghislain Roguin, Nick Abolins, M. Ringer","doi":"10.4043/31278-ms","DOIUrl":"https://doi.org/10.4043/31278-ms","url":null,"abstract":"\u0000 Abnormal hydraulic event detection is essential for offshore well construction operations. These operations require model comparisons and real-time measurements. For this task, physics-based models, which need frequent manual calibration do not accurately capture all the hydraulic trends. The paper presents a method to overcome existing limitations by combining physics-based models with machine learning techniques, which are suited for time series forecasting. This method ensures accurate and reliable predictions during the forecasting period and helps remove the need for frequent manual calibration of the hydraulic input parameters.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87769701","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":"Qualification Method for Cut Resistant Jackets for Fiber Mooring Ropes","authors":"Ø. Gabrielsen, K. Larsen, S. H. Gjøsund, Karl Johan Reite, Kurt Eide, H. Haugland, A. Leao","doi":"10.4043/30962-ms","DOIUrl":"https://doi.org/10.4043/30962-ms","url":null,"abstract":"\u0000 The Aasta Hansteen spar platform in the Norwegian Sea has a polyester rope mooring system. The anchors and large parts of the polyester ropes are outside of the safety exclusion zone granted by the Norwegian authorities. Fishing vessels cannot be denied as long as they are outside of the safety zone, and the polyester mooring ropes need to withstand abrasion loads from the possible fishing activity. A fishing activity study in 2013 defined probability for fishing, size of possible fishing vessels and type of fishing equipment. Numerical simulations of the mooring system and crossing fishing trawl equipment made it possible to establish trawl abrasion load cases, including trawl wire lengths, speed and contact pressure.\u0000 No jacket design or jacket material was at the time confirmed to withstand the established abrasion loads. The jacket solution to be chosen for the project thus needed to be specially developed, designed, tested and approved to give sufficient resistance against the established abrasion loads. Several vendors developed and offered different jacket solutions, and the selection of cut resistant jacket was dependent on adequate testing. Based on input and comments from Equinor and rope vendors, DNV constructed a test rig extension to their 2500T horizontal test bed, where the required length of trawl wire was pulled over the polyester rope with the needed contact pressure. Full-size (diameter) ropes with the proposed cut resistant jackets were tested, including break strength testing after the abrasion test.\u0000 This paper presents how the possible trawl activity was defined, the numerical simulation of trawl/mooring line interaction, the test rig setup and some test results of the trawl wire abrasion testing.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"83 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77133843","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 Innovative ECA Approach For Reeled CRA Welds And Its Validation Programme","authors":"R. Jones, T. Sriskandarajah, Daowu Zhou, James Hymers, Kieran Munro, Hung Hing Chan, G. Roberts","doi":"10.4043/31254-ms","DOIUrl":"https://doi.org/10.4043/31254-ms","url":null,"abstract":"\u0000 This paper presents an innovative defect growth ECA methodology for pipeline girth welds and its validation programme, applied specifically to reeling ECA of pipelines with under-matched strength welds.\u0000 The ECA method is a tear-fatigue approach that accounts for the blunting limit in JR curves during pipe spooling and reel-lay. Fatigue crack growth may occur by low cycle high stress fatigue and by tearing, but the latter only if the crack tip opening displacement exceeds the blunting limit.\u0000 Conventional ECA with BS7910 is limited because the weld's strength needs to be over-matched. Alternative industry methods for the application of FEA to under-matched strength welds are computationally more intensive than the presented innovative approach.\u0000 Fatigue crack growth for low cycle high stress fatigue is calculated using Paris’ Law in the approach but, if the crack tip opening due to the tearing mechanism is less than the blunting limit then tearing growth is zero. With the innovative method, if the crack tip opening displacement exceeds the blunting limit then the tearing defect growth is included. Hence, the method is a combined tear-fatigue approach.\u0000 Welded pipe strings were fabricated from pups composed of clad material; i.e. carbon backing steel pipe with a 3 mm layer of corrosion resistant alloy (CRA) on the inner circumference.\u0000 Each test string was approximately 10.5m long and fabrication was from a mix of six 0.5m length pups in the central zone of each string and two longer end pups. Three girth welds included EDM notches for test purposes which simulated planar flaws. The notches were on the extreme tension fibre, as the test string gets pulled to the reel former in a reeling test rig.\u0000 Full scale reeling simulations involved pulling the test strings up to 6 times to the reel former in a reeling test rig. Measurement of defect growth associated with the EDM notches was by scanning electron microscope (SEM), from specimen segments extracted from the test strings.\u0000 Predictions of defect growth were by finite element models in combination with pipe-specific data that was the outcome of an associated small-scale test programme.\u0000 Validation of the ECA-by-FEA approach is by a predictive best estimate study, for which there is excellent agreement between the measured values and the calculated defect growths. The ECA-by-FEA approach is conservative for project work, as shown by a high estimate study and an offset blunting limit study.\u0000 Early development of the ECA approach was for small diameter CRA pipelines during the execution of the Guara-Lula project (Sriskandarajah et al, 2015). The presented full-scale tests, innovative defect growth measurement by scanning electron microscope and the FEA and defect growth calculations were full validation of the approach, with pipe strings that had outer diameter of 323.9mm.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80847091","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":"Cost Effective, Digital, Fail-Safe Production Tree and Wellhead Actuator System","authors":"E. Johansen, D. Fredheim, R. Volkers, Dag Almar Hansen, Christian Petersen","doi":"10.4043/31240-ms","DOIUrl":"https://doi.org/10.4043/31240-ms","url":null,"abstract":"E&P companies are challenged with the cost-effective development of smaller and marginal fields, while ensuring safety for its crew and facing increasing regulatory requirements for further reducing emissions and environmental impact. Key enablers to achieve profitable development of smaller fields and maintaining safe production in remote locations is digitizing and automating the production chain and limit the need for on-site personnel. There are a number of safety critical valves on wellheads and production trees that have historically been manually or hydraulically operated and thus not suited for fully remote operations. In 2017, Equinor, Baker Hughes and TECHNI formed a Joint Industry Project (JIP) to develop a new electric actuator control system. The actuator system is designed for fail-safe, critical operations offshore and is subject to stringent safety design requirements. The key driver is reducing CAPEX and OPEX and environmental impact for offshore installations, while increasing availability of wells while providing improved monitoring and condition based, predictive maintenance. The electric actuator system developed in the JIP has a patent pending fail-safe mechanism with extremely fast closing time to ensure well containment during critical situations. It is designed to be a drop-in replacement for existing hydraulic actuator solutions and is suitable for most standard wellhead and tree designs, sizes, and pressure ratings. The all-electric solution contains a multitude of sensors, that, in combination with an integrated digital interface, enables data-driven insights from the systems in operation. The actuator development is currently at Technology Readiness Level (TRL) 4 on the API 17N, 0 to 7 scale. In 2020, the JIP consortium was awarded NOK 8.2 million (USD 950 000) by the Norwegian Research Council DEMO 2000 program to support the test and qualification program. TRL 5 testing is planned in first half of 2021 yielding it ready for field installation.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"109 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73504783","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":"Cost-Effectively Modernizing Offshore Drilling Line-Ups with DC Power Grids and Energy Storage","authors":"T. Steenberg, S. Settemsdal, Alf Olav Valen","doi":"10.4043/31264-ms","DOIUrl":"https://doi.org/10.4043/31264-ms","url":null,"abstract":"\u0000 This paper outlines an approach/solution which enables offshore operators to economically upgrade (i.e., modernize) drilling drive lineups with direct current (DC) based power grids and energy storage.\u0000 Many legacy drilling rigs in operation (and ones that are currently stacked/idled) utilize drilling drive technology that is currently obsolete or will be in the near future. Modernizing these rigs can often be an arduous and expensive undertaking. Most drilling setups feature lineups of individual variable frequency drives (VFDs) equipped with dedicated rectifiers, which control power output to motor/consumers, such as mud pumps, the top drive, draw works, rotary table, etc. These alternating current (AC) based setups have been used with success for decades. However, as fuel consumption and emissions, as well as space and weight, have become priorities, DC grid systems have gained interest.\u0000 The solution described in this paper is designed to enable drilling rig operators to upgrade to a modern DC power distribution system using the same footprint as the existing drilling line-up and with minimal modifications to cabling. Energy storage, such as batteries or supercapacitors, can also be integrated within the footprint to enhance the performance of drilling operations – for example through peak shaving and blackout prevention.\u0000 The solution/approach is highly flexible/modular and is derived from proven concept that has been deployed on hundreds of marine vessels worldwide. The paper provides a description of a solution that is being implemented on a jack-up rig in the Middle East. The new integrated drilling drive setup uses the same footprint, cable network, and communication principles as the rig's existing system and will be comparatively less costly and complicated to implement than simply swapping out existing drives (i.e., one for one replacement).","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"141 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75368824","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":"Digital Transformation and Automation of Flow Assurance Engineering Workflows Using Digital Field Twin","authors":"Harshkumar Patel, Jianlin Cai, Gautier Noiray, S. Bhowmik","doi":"10.4043/31017-ms","DOIUrl":"https://doi.org/10.4043/31017-ms","url":null,"abstract":"\u0000 Flow assurance is central to the design of a subsea production system and requires frequent interfacing with engineers from multiple disciplines. The objective of this paper is to demonstrate how cloud based digital field twin can be leveraged to automate subsea flow assurance engineering workflows and consequently, achieve efficient collaborations, faster and reliable designs, and reduced costs.\u0000 In this proposed workflow, engineers use a web application built on top of a cloud-based digital twin platform to perform flow assurance calculations and design analysis. The web based platform integrates multiphase flow simulators and other relevant engineering tools through python scripts. A user is only required to input design constraints and necessary basic information. The application acquires inter-disciplinary data (e.g. pipeline, layout, equipment, etc.) and automatically performs pre-processing, model setup, simulation, and results processing in the background and make results available to all the users at the front-end.\u0000 The digital flow assurance platform replaces traditional workflows requiring use of different standalone engineering software, and frequent exchange of information with other engineering teams in form of documents and spreadsheets. The proposed cloud-based workflow allows engineers to focus on technical analysis by eliminating several manual and repeating processes such as accessing different software, creating models, results extraction and formatting, etc. The ability to share results in form of auto-generated reports and formatted spreadsheets; minimizes human errors and promotes information exchange and transparency among project team members from different disciplines. The cloud based platform enables engineers to work on a same project from different geophysical locations and devices. Overall, this digital flow assurance workflow significantly improves engineering efficiency, save costs, and allows faster and reliable concept design and FEED (Front End Engineering Design).\u0000 The ideas widely discussed for flow assurance digitalization typically include use of data analytics and machine learning, virtual flow metering, real time data monitoring, predictive analytics, etc. This paper, however, presents novel practical idea to bring digital transformation to the way flow assurance engineers work and collaborate.","PeriodicalId":10936,"journal":{"name":"Day 2 Tue, August 17, 2021","volume":"178 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2021-08-09","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86976928","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}