Day 2 Wed, September 06, 2023最新文献

{"title":"Low Cost Electrochemical Ammonia Cracking and Fuel Cell","authors":"Chetan Laddha","doi":"10.2118/215581-ms","DOIUrl":"https://doi.org/10.2118/215581-ms","url":null,"abstract":"\u0000 Ammonia is a dense energy carrier with high energy density and established supply chain for transport, and storage of green energy. Ammonia is a common commodity used in the fertiliser and chemical sector and has a potential to become an affordable and sustainable energy carrier to meet growing demand for industrial decarbonisation. This paper describes an innovative ceramics-based solid oxide fuel cell technology for conversion of ammonia into fossil fuel parity energy at a thermal efficiency of 85%. The technology is based on proton conducting ceramics (PCC) electrochemical pathway which eliminates NOx emissions by design and ammonia slippage by catalyst performance and reactor design. The technology has been developed over the last 7 years and the ammonia utilisation capabilities has been proven through demonstrations conducted for O&G and industrial companies. The technology uses low-cost and widely available ceramics-based catalyst. The technology is particularly suited for industrial decarbonisation because of the ability to yield high efficiency and the ability to produce low-cost heat at 700C and hydrogen as byproducts.","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"79 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122522552","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":"Geomechanical Analysis of Caprock Integrity and Fault Stability for Greensand CO2 Storage Project Feasibility","authors":"A. Younessi, E. Kårstad, P. Basu, M. Larsen, O. Burachok","doi":"10.2118/215529-ms","DOIUrl":"https://doi.org/10.2118/215529-ms","url":null,"abstract":"A comprehensive geomechanical assessment is carried out to investigate the upper pressure limit of CO2 injection for the depleted oil Frigg Sand reservoir in Nini field, offshore Denmark. The mechanical stability of the Frigg Sand reservoir, shale caprock and key intersecting faults were investigated under the forecasted CO2 injection plan using a field-scale coupled finite element model built for the target storage reservoir. The field-scale geomechanical model is built by preparing a 3D grid which covers the entire Greensand field structure including the basement and overburden up to the seabed. The geomechanical properties and parameters are constrained using the well-centric data and propagated in 3D grid using geostatistical approach combined with surface seismic data. A finite element model is prepared and coupled with the reservoir flow dynamic model for the interested zone of the studied area. The results of the finite element model are used to investigate the integrity of the caprock and stability of the faults over the life of the field. The results of the finite element simulation shows that the calculated minimum principal stress does not change its state to tension in any part of the field. However, a reservoir pressure above the minimum principal stress magnitude in base of the caprock may increases the risk of failure in the caprock. Hence, considering the uncertainty for the lower bound of the minimum principal stress, the risk of failure in the caprock is low until the Frigg Sand reservoir pressure exceed the estimated threshold pressure. The results also show that there is no risk of shear failure in the caprock for the entire studied area. The fault stability analysis shows that no risk of fault reactivation exists in the overburden. However, some faults may reach the critical stress state in the reservoir with high injection pressures. A reactivation in the reservoir layer may extend to the overburden and increase the risk of caprock integrity failure. Overall, the most critical mode of failure is the possible tensile failure which defines the safe operational limit for the Frigg Sand reservoir. The thorough analysis using field scale finite element simulation coupled to the reservoir flow dynamic helped to capture the risk associated to the CO2 injection operation and optimize the injection plan.","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122546103","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":"The Evolution of UDAR Technologies for Risk Mitigation in Geostopping Applications","authors":"Supriya Sinha, Frank Antonsen, N. Clegg, A. Walmsley, Brígido Vicuña, B. Danielsen, M. V. Constable, Marta Prymak-Moyle","doi":"10.2118/215553-ms","DOIUrl":"https://doi.org/10.2118/215553-ms","url":null,"abstract":"\u0000 Complications during drilling and completion operations caused by subsurface geology have a significant impact on rig time, cost, assets, and even human life, if risk and incident severity is not well understood. Risk and tolerance evaluation processes are essential for completing successful drilling programs and final casing designs. While log-based correlation methodologies can be used, they are limited to scenarios where appropriate offset well data control exists, and they only provide information after the hole has been drilled. The development of technologies that provide warning of a hazardous zone before it is penetrated are therefore desirable. Ultradeep Azimuthal Resistivity (UDAR) tools are deployed for such scenarios and provide high value when used in integrated interpretations to identify hazards ahead of drill bit.\u0000 Seismic data is used as a first step to predict and map subsurface characteristics such as pressure regimes, faults, and fluid contacts. Offset and pilot hole data further complements assessment of these features enabling more precise risk assessment. Commonly, near-bit measurements such as resistivity and gamma ray have been used for these correlations in conjunction with sonic and density measurements. The mapping of horizons from seismic data can have 10s to 100s of meters of vertical uncertainty, while offset data in exploration campaigns is typically sparse and near-bit measurements require drilling into the zone of risk. Pilot holes therefore become a costly necessity, however, if sufficient resistivity contrast exists UDAR can be used for remote boundary mapping, without drilling into the geohazards, thus reducing cost and de-risking the operation.\u0000 This paper presents several case studies where UDAR technology was deployed in near vertical to horizontal wells to map geohazards before they were penetrated using different techniques, allowing optimization of the stopping point in diverse scenarios. This includes a case where the technology was used to geostop in a horizontal section prior to penetration of a major structural sealing fault plane that bounded the productive reservoir interval. UDAR has been successfully used to manage seismic uncertainty, support the decision-making process for core point selection, reduce exposure of unstable overburden shales and geostop above abnormal and subnormal pressure zones.\u0000 Mapping a geohazard and proactively stopping at a particular depth is a complex operation and evaluation of the rock properties with respect to the sensitivity of the measurements and uncertainty in the models is important. Limitations in measurement sensitivity can lead to potential masking of top reservoir picks and increased uncertainty in both boundary positions and the inverted resistivity. Improvements such as new UDAR transmitter designs being embedded into Rotary Steerable Systems allow near-bit placement of this technology, demonstrating the continual evolution of this technology and how it ","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"44 2","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114116293","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 Technical Framework for Assessing Offshore Geothermal Opportunities in and Around Existing Oil and Gas Assets","authors":"K. Pasturel, V. Barres-Montel, W. Harrar, K. Watt","doi":"10.2118/215504-ms","DOIUrl":"https://doi.org/10.2118/215504-ms","url":null,"abstract":"\u0000 This paper provides an overview of a Geothermal Assessment Project (GAP) completed to assess the geothermal energy resource in and around an operational HPHT field on the UKCS. It demonstrates a new methodology to identify, assess and determine the amount of electrical power that might be realised from the geothermal resource and associated field infrastructure, and investigates both existing and future opportunities.\u0000 Geothermal energy adoption into oil and gas net-zero portfolios remains relatively unexplored. This paper shares the results of the design and implementation of a novel integrated workflow to assess and evaluate the geothermal energy potential of producing offshore oil and gas assets from subsurface, wells, and topsides perspectives. The workflow is designed to allow operators to determine potential electrical power production from geothermal sources within existing field infrastructure alongside a model of the opportunity it provides to reduce CO2 emissions.\u0000 Three geothermal production scenarios are defined, that are: proven co-produced fluid reserves, contingent co-produced and enhanced fluid resources and prospective exploratory geothermal resources. Existing and sanctioned production forecasts were used along with reservoir modelling to examine aquifer behavior and the ability for enhanced and sustained water production. Screening and complexity matrices were applied to identify and rank relevant reservoir plays and candidate wells. Process flow diagrams were interrogated to establish potential tie-in points for heat to power equipment and equipment characteristics required for enhancing heat to power generation were considered. The overall opportunity was also risk assessed from a flow assurance perspective.\u0000 Results of the study are discussed in terms of the challenges and opportunities that exist to co-produce geothermal energy within the constraints of an established oil and gas development. It illustrates the value of developing a structured framework to allow assessment and benchmarking of geothermal resources. Furthermore, the nuances of modelling aquifer response and the behavior of enhanced water production as it travels from the reservoir to the process facilities are considered. The study shows that the production characteristics that favor geothermal energy adoption on a producing asset are elevated temperature profile, high water production rates, presence of injection support and/or artificial lift, and production lifespan.\u0000 This study identified, assessed, and compared geothermal development models that might support geothermal co-production or repurposing of hydrocarbon assets. The result was a clear picture of near and long-term geothermal power options that are replicable across asset portfolios, that provides operators with additional strategies when considering lifecycle field activities and underlines the potential commercial value of including geothermal in field development. The study concludes that op","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"23 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116344734","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":"Deep Insight into Electrical Submersible Pump Maintenance: A Predictive Approach with Deep Learning","authors":"Ramez Abdalla, Denis Nikolaev, David Gönzi, Roman Manasipov, Andreas Schweiger, Michael Stundner","doi":"10.2118/215596-ms","DOIUrl":"https://doi.org/10.2118/215596-ms","url":null,"abstract":"\u0000 Artificial lift systems play a crucial role in the oil and gas industry by maintaining or enhancing production rates through the conversion of kinetic energy into hydraulic pressure. However, identifying abnormal performance and preventing failures remains a major challenge. Failures occur when key parameters deviate from safe operating conditions, leading to downtime and loss of production volumes. To address this challenge, the objective is to establish repeatable frameworks for constructing predictive models through the utilization of deep learning algorithms. These models provide support for engineering and operational teams through a connected alarm system that sends prescriptive notifications, enabling prompt and informed decision-making.\u0000 We approach the problem of predictive maintenance for electrical submersible pumps using a multi-task classification method. The different types of faults that can occur in these pumps are treated as individual tasks, and each task is represented by different severity grades to be predicted. To handle this multi-task classification problem, a unique model is trained end-to-end by defining a multi-task loss function. We have evaluated two different architectures for feature extraction, including a 1D CNN and an LSTM with an attention mechanism. The 1D CNN architecture consists of two convolutional and max pool layers, along with batch normalization to facilitate training. The LSTM architecture with attention was found to perform better than the vanilla LSTM in this multi-task classification problem.\u0000 This study evaluated two architectures for their performance in the predictive maintenance of electrical submersible pumps: 1D CNN and LSTM with an attention mechanism. The results showed that the LSTM with attention using lookback architecture exhibited the best performance and was the easiest to train. The 1D CNN had a comparable performance but exhibited some overfitting in the current configuration. These findings highlight the potential of using 1D CNNs for this application and the importance of attention mechanisms in LSTM models.\u0000 The maintenance of Artificial Lift Systems (ALs) requires significant resources and is traditionally performed through reactive process monitoring. An automated predictive maintenance solution using deep learning has been developed, including predictive models and a best practices guideline. This work introduces a novel automated system to reduce failures by analyzing real-time sensor data and statistical parameters to predict failures in ALs. The predictive tool supports work over plans including ESP replacement strategies, and reduces production losses.","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"401 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126576899","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 Feasibility Study of Geothermal Energy Extraction in the Baram Basin, Sarawak Using Numerical Reservoir Simulation Based on Analogue Data","authors":"M. Bataee, R. Carter, Z. Hamdi, Z. Bennour, H. K. B. Mahmud","doi":"10.2118/215554-ms","DOIUrl":"https://doi.org/10.2118/215554-ms","url":null,"abstract":"\u0000 Renewable energy sources are becoming favorable choices nowadays, due to Regulators’ desire to respond to the challenges of climate action and meet the need for global reduction of CO2. Geothermal energy is a recognized source of clean, low carbon renewable energy, however, selecting an optimized location for extracting this heat energy from the subsurface depends on many factors, and there are always risks involved with obtaining accurate and realistic values for the key parameters. In this project, the feasibility of geothermal energy extraction was studied using reservoir simulation, based on publicly available analogue data. The investigation focused on the Baram Basin, located in the state of Sarawak, Malaysia. Published data from existing fields and recent exploration and appraisal activities are used for estimating the likely range for both surface and subsurface parameters. Different geothermal development scenarios were run with and without injection wells to investigate the effect of formation pressure on sustainable water production. Results of this study indicate that optimum well spacing of 300m was predicted for maximum sustainable heat extraction. Results of the work compare the amount of enthalpy derived from production with estimates of Levelized Cost of Electricity. Simplified economics were run to explore commercial competitiveness. Sensitivity analysis has explored the key risk factors in this study and reveals the likely ranges for recoverable thermal energy for a profitable project. Geothermal energy sets an example for other energy providers by offering renewable baseload power, reducing emissions, enhancing energy independence, creating jobs, utilizing heat for various applications, and emphasizing long-term resource availability, inspiring greater sustainability, reliability, and environmental stewardship in energy generation practices.","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"144-145 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134496060","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":"Hybrid Workflows- A History of Tomorrow","authors":"B. Moradi, K. K. Ask, L. Alessio","doi":"10.2118/215492-ms","DOIUrl":"https://doi.org/10.2118/215492-ms","url":null,"abstract":"\u0000 This study provides an overview of the evolution of technology in the reservoir modeling field, discussing past, present, and future advancements. It explores how technologies such as central and graphics processing units have enabled engineers to increase the number of simulation grids from 500,000 to 1 trillion cells over the last 20 years. The paper also examines data-driven workflows that have accelerated the reservoir modeling process to a few weeks, highlighting their limitations. To address these limitations, the study introduces hybrid physics-guided data-driven models as a modern digital tool for mapping potential remaining oil in brownfields. These hybrid workflows combine the strengths of both physics-guided and data-driven models, overcoming the weaknesses of each approach. Two case studies, located in the North Sea and the Middle East, are reviewed to demonstrate the effectiveness of these hybrid workflows. The comparison of the water saturation map generated by the hybrid workflow with the contact movement calculated from 4D seismic data in the North Sea field shows a strong correlation, indicating a reliable match between the two maps. In the Middle East case study, the performance of four infill wells calculated by the hybrid workflow is evaluated against the actual outcomes of post-drilling activities. The results show that, except for one of wells, the actual outcomes align with the predicted trends, falling within the P10-P90 band. The paper emphasizes the novelty and benefits of using hybrid workflows, as they enable the generation of potential remaining oil maps in a few days—a task that is challenging with conventional numerical simulation workflows. These hybrid workflows offer significant time and cost savings while maintaining high fidelity. The advanced technologies discussed in this study facilitate the implementation of practical digitalization strategies across all disciplines in the industry, ushering in a new era of data-driven innovation.","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"11 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123744930","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":"Automated Non-Destructive Weld Inspection in Splash/Subsea Zone","authors":"K. Husby, Magnus Bjerkeng, J. Thielemann, Johannes H. Denstadli, Christian Eirik Johnsen","doi":"10.2118/215588-ms","DOIUrl":"https://doi.org/10.2118/215588-ms","url":null,"abstract":"\u0000 Jacket structures all over the world are now reaching the limit of their estimated service life, but new discoveries and improved production methods require lifetime extension of the assets. In this paper, an automated underwater robot and a Non-Destructive Testing (NDT) eddy current probe for Alternating Current Field Measurement analysis of jackets main welds, is presented. This robot makes integrity testing possible, which often is required for lifetime extensions.\u0000 Once the robot is attached to any welded brace, it has the potential to move around the pipes and at the same time control the position of the eddy current probe. The robot is guided by a 3D vision system that includes two lasers and two cameras. The camera system also supplies visual information useful for the pilot. The quality of the measured data is improved by using an eddy current probe that tolerates challenging conditions. The robot collects the measured results and stores them together with positioning information.\u0000 Eddy current surveys in the splash zone is challenging, time consuming and exhaustive for the pilots. Prototypes of the robot and eddy current probe has been tested in lab. The results confirm that this robot will ease the pilot's job and help the operator to make more accurate detections of the jacket integrity.\u0000 The robot control system can operate in either a First Person View (FPV) mode where the pilot has full and easy control, or the robot can operate in closed loop mode where the robot places the eddy current probe in optimal alignment against the weld.\u0000 The eddy current probe includes multiple Alternating Current Field Measurement sensors that tolerates some miss alignment, lift-off, and even variations in permeability.\u0000 The robot presented has already been used offshore, but the newly added 3D vision and control system will reduce measurement time and increase quality of the data. In addition, the eddy current probe presented will make it easier for NDT technicians to stay focused and to make correct decisions.","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"52 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114564803","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":"Maximizing Technology for the Energy Transition: An Organisational Innovation Adoption Culture Survey","authors":"Ruby Roberts, R. Flin, Luca Corradi","doi":"10.2118/215557-ms","DOIUrl":"https://doi.org/10.2118/215557-ms","url":null,"abstract":"\u0000 Accelerating our transition towards a net zero future is imperative for both the longer-term success of the energy sector and providing energy security for wider society. An integrated North Sea offers significant opportunities for working towards these targets but also represents challenges for the energy sector. Innovation has been the backbone of the oil and gas industry, continuing to provide many solutions for a smooth transition. Whilst there have been increasing efforts to facilitate innovation, the oil and gas industry has retained a reputation for being conservative and reluctant to adopt new technology with many companies preferring to be \"fast followers\". Consequently, it is essential for the success of the energy transition to address the resistance to innovation adoption.\u0000 Our previous research has shown that that psychological factors impact on technology adoption decisions in the oil and gas industry, such as gatekeepers’ attitudes, motivations, and risk perception, as well as social influence – all with the potential to act as innovation barriers. Organisational culture was found to have a significant effect on how people respond to and introduce technology into their organisation. Whilst the role of organisational culture is recognised for key strategic priorities, such as safety, less is known about the culture that values and facilitates innovation uptake. In response to this gap, a pioneering organisational innovation adoption culture questionnaire was developed based upon our earlier findings and extant literatures. Having been successfully piloted with 12 operating companies in 2021, in this study it was refined and validated with one international oil company.\u0000 The refined innovation adoption questionnaire consists of 36 items covering eight factors: Collaboration, Innovation Value, Leadership & Vision, Implementation Context, Open Communication, Organisational Learning & Competence, Rewards & Recognition, and Risk Taking for Technology adoption. The questionnaire was run in an online survey across the company with 455 participants (85%working onshore and 13% working offshore, 2% did not indicate). The results provided a valuable snapshot of this company's innovation adoption culture across multiple locations and business areas. To examine the link between innovation adoption culture and innovation adoption behaviour, two questions asked about the current technology innovation adoption status in the company. An overview of the development of the measure and results of a psychometric analysis (criterion validity) of the questionnaire will be given, as well as recommendations and best practices on how to support an innovation adoption culture. This novel survey tool can offer valuable insights for companies looking to strengthen their innovation uptake profile, maximising the potential of innovation as part of their energy transition.","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"56 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128234217","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 New Innovative Cement Evaluation Method for Highly Deviated or Horizontal Wells","authors":"A. Kumar, K. Singh, D. S. Oliver, S. Dutta","doi":"10.2118/215510-ms","DOIUrl":"https://doi.org/10.2118/215510-ms","url":null,"abstract":"\u0000 Evaluation of cement integrity to prevent fluid migration in the annular space behind casing may become challenging under certain well conditions. Conventional cement evaluation tools are useful in most scenarios, but in highly challenging operations (deviated or horizontal wells), there is a pressing need for more advanced cement evaluation and processing techniques to increase the confidence of the measurements for the evaluation of wellbore integrity.\u0000 Pulse-Echo and/or Flexural wave measurement, along with sonic measurements, are generally run in tandem for improved cement evaluation. The method relies on knowing the wellbore fluid properties (acoustic velocity and acoustic impedance), which may change in deviated or horizontal sections of a well due to mud settling or mud segregation with lighter components on the high side and heavier components on the lower side of the well. This segregation phenomenon, if not accounted for, results in erroneous cement interpretation answers with uncertainty, such as low-acoustic impedance stripe in the direction of heavier mud components. A new advanced ultrasonic technology and its embedded unique inversion processing known as R+, based on 3-parameter inversion approach is developed, which first computes the wellbore mud impedance 360 deg and then uses it as an input to compute the annular material acoustic impedance accurately. This method can also reveal wellbore conditions such as mud settling and segregation.\u0000 This paper demonstrates the application of new advanced ultrasonic tool and the R+ inversion processing through multiple case studies. In all the cases explained in the paper, we see that due to mud segregation in the borehole, it was difficult to identify true annular conditions. The R+ inversion method was used to confirm the wellbore fluid heterogeneity. All the case studies compare cement evaluation performed using the classic T3 method with R+ inversion method. The uncertainties faced due to mud segregation inside the wellbore were properly addressed with the new R+ inversion method, and the final cement interpretation helps the operators in taking operational decisions in time.\u0000 The advanced ultrasonic technology and R+ inversion method will ensure accurate cement evaluation in challenging wellbore environments where mud segregation is expected irrespective of casing sizes and cement types. With accurate cement evaluation, the operators can avoid unnecessary costly cement remedial operations at any point (new well, intervention, plug and abandonment), thus impacting the rig activities.","PeriodicalId":213852,"journal":{"name":"Day 2 Wed, September 06, 2023","volume":"63 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-09-05","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128771961","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}