Day 2 Tue, November 13, 2018最新文献

{"title":"Customization and Implementation of Geomechanics to Successfully Drill High Angle Wells through Ahmadi and Wara Shales, Greater Burgan Field, Kuwait - A Case Study","authors":"Nitin L. Rane, O. Al-Zankawi, A. Al-Ghareeb, Ebraheem Al-Duraia, E. Hussain, Rajesh Ranadive, Hemant Singh, S. Imtiaz, S. Perumalla, D. G. Rao, D. Upreti, T. Podder, Loui Otri, Ravi Ramaratnam","doi":"10.2118/192841-MS","DOIUrl":"https://doi.org/10.2118/192841-MS","url":null,"abstract":"\u0000 The mature Greater Burgan field is the largest clastic oil reservoir in the world producing from multiple clastic reservoirs. With growing surface area congestion affecting rig moves, current wells are drilled with high deviation often through unstable overburden shales. Well trajectories are getting more complex, resulting in a large increase in hole instability events associated with stuck pipes, loss of bottom hole assemblies often leading to side-tracks, challenging well logging conditions and well completion operations. This paper discusses a holistic and practical geomechanical approach to solve the instability problems, based on understanding the rock failure mechanism of shale, and also discusses the implementation of an integrated solution to drill, log and complete the wells successfully.\u0000 A thorough geomechanical analysis was done on several wells. Drilling data analytics helped to understand the relationship among formation instability, well trajectory and mud parameters. Lab tests (chemical and mechanical) were performed to determine the chemical and mechanical behaviour of the rock and its interaction with drilling fluid. Anisotropic shale strength tests were targeted to know the rock strength variation with respect to angle of attack. Geomechanical models were prepared and calibrated with observations of drilling problems. Based on integration of models and experiences, effective solutions were devised to implement at well planning as well as drilling stages.\u0000 A combination of measured and modelled parameters suggested that multiple failure mechanisms are active to induce shale failure including (a) stress induced borehole breakouts, (b) chemoporoelastic interaction of mud and rock fluid and (c) weakening of shale bedding planes and micro fractures. A customized real-time geomechanical monitoring solution was implemented for improved drilling performance and efficient completion of new wells.\u0000 Specific mud design and mud weights for drilling high angle wells (65-70 deg) were generated and used in real-time while drilling. With the help of LWD and mud logging data, real-time decisions were taken based on well behaviour to drill the wells in a single casing section. Wireline logging and lowering of completion string was completed without any resistance even after the long section of shale was exposed for several days. This entire re-engineering of the process was accepted as a cost-effective and efficient solution that is being recorded as a best practice for implementation in future wells.\u0000 Integration of diverse disciplines (geomechanical, geochemical, petrophysical and drilling engineering) was successfully implemented to drill a complex well. Real-time geomechanics along with customized drilling fluid and drilling practices enhanced the drilling efficiency. This integrated solution is expected to significantly reduce non-productive time in future upcoming wells with complex well profiles.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80538649","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":"Detection of Stuck Pipe Early Signs and the Way Toward Automation","authors":"Abrar A. Alshaikh, M. Albassam, S. Gharbi, A. Al-Yami","doi":"10.2118/192975-MS","DOIUrl":"https://doi.org/10.2118/192975-MS","url":null,"abstract":"\u0000 The earlier a stuck pipe incident is predicted and mitigated, the higher the chance of success in freeing the pipe or avoiding severe sticking in the first place. Time is crucial in such cases as an improper reaction to a stuck pipe incident can easily make it worse. In this work, a novel and practical model was developed using real-time drilling data to automatically detect leading signs of stuck pipe during drilling operations and communicate the observations and alerts, sufficiently ahead of time, to the rig crew for avoidance or remediation actions to be taken.\u0000 The model uses key drilling parameters to detect abnormal trends that are identified as leading signs to stuck pipe. The parameters and patterns used in building the system were identified from published literature and historical data and reports of stuck pipe incidents. The model is designed to be implemented in the real-time drilling data portal to provide an alarm system for all oil and gas rigs based on the observed abnormalities. The alarm is to be populated on the real-time environment and communicated to the rig crew in a timely manner to ensure optimal results, giving them more time to prevent or remediate a potential stuck pipe incident.\u0000 Testing the model on several wells showed promising results as anomalities were detected early in time before the actual stuck pipe incidents were reported. It further facilitated better understanding of the underlying physics principles and provided awareness of stuck pipe occurance. It improved monitoring and interpretating the drilling data streams. Beside such pipe signs, the model helped detecting signs of other impeding problems in the downhole conditions of the wellbore, the drilling equipment, and the sensors.\u0000 The model exceptionally uses the robustness of data-based along with the physics-based analysis of stuck pipe. This hybrid model has shown effective detection of the signs observed by experts ahead of time and has helped providing enhanced stuck pipe prediction and risk assessment.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83337988","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":"Think Big - Start Small in Asset Performance Management","authors":"Johan Ferket","doi":"10.2118/193162-MS","DOIUrl":"https://doi.org/10.2118/193162-MS","url":null,"abstract":"\u0000 Asset-intensive companies face tighter maintenance budgets, stricter regulations and increased pressure to improve asset performance, whilst confronted with aging assets and workforce. Managing an asset with these challenges requires informed decision-making based on insight, knowledge and forecasting. Data is a powerful tool to achieve this goal.\u0000 ‘Internet of things’ innovations have led to a rapid increase in the availability of technical and business data. A few years ago, techniques that were complex and expensive are now more affordable, accessible and increasingly important in order to compete in this world of rapid change.\u0000 Field data is faster and immediately available for processing, while more relevant measurements and observations of similar or better quality are leading to more reliable information for decision-making.\u0000 The transition from data to information has been made possible through development in the usability of applications in the field of data science, and more advanced software and information systems are on the market for data analysis, diagnostics and simulation.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"136 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77509403","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 Unique and Blended Approach to Nationalisation","authors":"K. Osseiran","doi":"10.2118/192727-MS","DOIUrl":"https://doi.org/10.2118/192727-MS","url":null,"abstract":"\u0000 \u0000 \u0000 Governments and National Oil Companies, alongside International Oil Companies, are working to develop competent national workforces and drive In-Country value. This paper will demonstrate a unique, blended approach to fast track competency development to meet this challenge. Petrofac, through its training services business, has reduced training timelines considerably through the integration of innovative technology solutions, hands on practical training and modern classroom learning within its technical national workforce development programmes.\u0000 \u0000 \u0000 \u0000 For many years Petrofac has been delivering training to the oil and gas industry. It has practical experience running large scale technical national workforce development programmes in the Middle East, Africa and Asia. Petrofac will use this experience to explore how combining the below systems and facilities can allow for a unique approach to training, with drastic benefits around accelerated timing, reduced budget, increased safety and improved graduate skillsets:\u0000 \u0000 \u0000 \u0000 By blending workshop, classroom, augmented reality and experiential training Petrofac has been able to equip students with extensive, hands-on, practical experience. This experience provides the necessary skills and qualifications so that when they are back on site, the time until they can work productively and autonomously is much reduced.\u0000 Our approach is also:\u0000 Visual: Augmented reality has enabled students to see the inner workings of key equipment and to visualise equipment in a way that would not be possible on site and in some cases in real life.\u0000 Realistic: Training plants that replicate live hydrocarbon facilities further provide real world experience, such as at the ADNOC Technical Academy (ATA), PETRONAS INSTEP and TPO in Oman.\u0000 Bespoke: Petrofac's collaborative approach with ADNOC, enabled the Company to develop facilities and curriculum to address the specific competency gap closures required for their personnel.\u0000 Safe: Process plants drastically reduce the risk to safety of the students, along with eliminating the risk of loss of production revenue that would occur for training on a live plant.\u0000 \u0000 \u0000 \u0000 Petrofac's most recent centre, Takatuf Petrofac Oman, is truly cutting-edge, having opened in April 2018, and bringing together our best practice from the training of over one million students, to deliver a next generation approach to training. The augmented reality simulator that Petrofac will demonstrate is cutting edge, and our blended approach is a truly unique offering that will show a new way of delivering training.\u0000","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"30 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81647638","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":"Comparison of Steam Front Shape During Steam Flooding Process Under Varying Steam State Condition: Numerical Analysis","authors":"Fengrui Sun, Yuedong Yao, Guozhen Li, Xiangfang Li, Jian Sun","doi":"10.2118/192996-MS","DOIUrl":"https://doi.org/10.2118/192996-MS","url":null,"abstract":"\u0000 It has been reported that superheated steam can greatly increase the oil recovery efficiency. After superheated steam injection, the viscosity of heavy oil is greatly reduced. Besides, the permeability of the rock is increased. However, this previous works were focused on the chemical respects of oil displacement mechanisms by superheated steam injection. The difference in physical heat transfer between superheated steam and wet steam has not been revealed.\u0000 At present, there is a lack of study of its physical heating on the increase of productivity. In this paper, a numerical study is conducted to reveal the difference between superheated steam and wet steam during the steam flooding process. The contribution of physical heating on the productivity is studied.\u0000 Simulation result show that: (a) The effect of physical heating of superheated steam can be neglected. The contribution of chemical reactions of superheated steam with heavy oil and rock minerals is the dominant factors for oil recovery mechanisms under superheated steam injection. (b) When the temperature is higher, the pressure wave propagates more widely. However, the difference in pressure field between superheated steam and wet steam with a steam quality of 1.0 is negligible. (c) There exists severe steam fingering phenomenon under superheated steam injection. This is because the superheated steam is completely vaporized which greatly increases its percolation capacity.\u0000 This work sheds light on the contribution of physical heat transfer on temperature spread in reservoir under varying steam state during the steam flooding process. This work pointed out that the study of chemical reactions should be the research direction of the next step in oil displacement mechanisms by superheated steam injection.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"15 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89427524","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":"Reservoir Health Indicators Driving Performance Through Data Analytics","authors":"Mohamed Al Marzouqi, L. Saputelli, M. Abdou, R. Narayanan, R. Mohan, A. Ismail, Alvaro Escocia","doi":"10.2118/192881-MS","DOIUrl":"https://doi.org/10.2118/192881-MS","url":null,"abstract":"\u0000 Reservoir management leverages on surveillance practices to diagnose reservoir conditions which aid in the identification of treatments that maximize the business value of reservoir deliverability while protecting the long-term sustainability. However, operators struggle to exploit value from data because of big data avalanches, data dispersion and ambiguity in the data definitions across department and companies.\u0000 Typically, operators are satisfied by meeting average targets within certain tolerance. This is obtained by calculating the ratio of plan vs actual performance. In this work, reservoir management excellence is pursued by an integrated review of leading and lagging indicators, which are represented by continuous and proactive KPI computation and monitoring.\u0000 The objective of this work is to simplify reservoir performance data analysis on such a way that performance management is decomposed in 5 key areas (business, operation, quality, recovery and predictability) driving continuous improvement, and yet establishing a culture of variance reduction and sustainable consistency in results delivery.\u0000 The scope of this work entails the definition and case studies of implementing performance indicators that facilitate the analysis of reservoir performance and field development strategic decisions. Such indicators are leading pointers of quality, recovery status and predictability, which ultimately affect business and operations performance at multiple time scales.\u0000 A solution to continuously compute reservoir health indicators and assure reservoir performance is implemented across various assets, leveraging big data management with automated scheduled extraction, transformation and loading (ETL) capabilities. Raw and calculated data are further provided to end user via commercially available business intelligence (BI) analytics. Each indicator measures the compliance between actual and planned values, and the roll-up is done by computing the volume-weighted average of each underlying element. For this purpose, key performance indicators (KPI) are calculated and creatively concatenated from well to reservoir level, from reservoir to field level and from the field to the operating company level.\u0000 KPI rollout showed a new way to report and monitor performance on a proactive, sustainable and cost-efficient manner. Some of the realized benefits included reducing more than 90% the time require to identify variances between actual performance and expectation during the execution of projects and improving compliance to the reservoir management guidelines from ~61% to ~84%. This ensures long-term production sustainability while mitigating shortfalls proactively.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83734140","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":"Use Metaheuristics to Improve the Quality of Drilling Real-Time Data for Advance Artificial Intelligent and Machine Learning Modeling. Case Study: Cleanse Hook-Load Real-Time Data","authors":"S. Gharbi, Moataz A. Ahmed, S. Elkatatny","doi":"10.2118/192810-MS","DOIUrl":"https://doi.org/10.2118/192810-MS","url":null,"abstract":"\u0000 The drilling engineers are overmild with huge amount of data-points, argue the need to develop Artificial Intelligent (AI) and Machine Learning (ML) models to crunch these huge amount of data generating decision-like information. There are a lot of challenges developing such approach, varying from computational power, lack of subject matter experts, and develop the optimum algorithm. But the main bottleneck is the quality of the data. Regardless of how advance AI/ML model, if the data is bad, the model will generate bad result; garbage-in garbage-out. The scope of this paper is to use metaheuristics models to improve the data quality. The process start by extracting Hook-Load drilling real-time data. And explore the raw data quality using visualization and statistical methods. Then apply several Metaheuristics models to generate functional approximation equation that identify/ follow the trend of the good-quality data. This will be by employ multiple scenarios with different degree of randomness that lead to the highest matching which generate the high quality level. The process will cover different technique including Greedy, Hill-Climbing, Random Search, and Simulated Annealing. During this process hundreds of thousands of scenarios will be conducted to simulate the Hook-Load data, to identify the optimum functional approximation equation that match the best data quality. Which can then safely integrated into the advance Artificial Intelligent and Machine Learning models. Running such process require an expensive computational cost, since it includes huge amount of real-time data need to be process under complex advance models. Moreover it require a deep understanding of the internal process of each models to ensure finest manipulating them to get the optimum data quality result. Running these scenarios, lead successfully to functional approximation that spill the data behavior, with Mean Absolute Error (MAE) equal to 10.5. It is worth height that functional approximation is very expensive in term of time and complexity, but it generate the highest quality result, leading to better AI/ML model. Moreover it is the most dynamic approach allowing it to be applied in other drilling real-time parameters as well. Utilizing Metaheuristics approach to improve the data quality is new to the upstream domain in general, with almost no application in drilling in specific. The novelty is to introduce this advance technique into the drilling real-time data domain, it will sharply improve the data quality leading to higher Artificial Intelligent and Machine Learning prediction/ analytical models. It worth mentioning that such approach will run all those simulation/ scenarios and adjust itself automatically with almost no manual interference. Leading to self-data-driven data-quality model.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"558 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74713124","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integrated Field Development Planning for Enhanced Condensate Recovery ECR and Gas Storage in Mature Gas Condensate Fields","authors":"H. Saradva, Siddharth Jain, Mark Sarssam, M. Hamadi, M. Robert","doi":"10.2118/192647-ms","DOIUrl":"https://doi.org/10.2118/192647-ms","url":null,"abstract":"\u0000 Sharjah National Oil Corporation (SNOC) currently operates 3 fractured carbonate mature gas-condensate fields with some 35 years of production history. Until recent years these fields were operated by leading International Oil Companies (IOCs) which utilised some of the then latest technologies, such as underbalanced coil tubing drilling in order to maximise the production rate.\u0000 The reservoir development and management scheme, however, did not involve gas re-injection to maintain reservoir pressure above the dew point. This led to production by simply blowing-down the field. Since there was negligible aquifer support the reservoir pressure declined rapidly and the dew point pressure was reached within 3 years, resulting in condensate drop-out in the reservoir. It is estimated that more than half of the original condensate in place still remains in the reservoir, although more than 97% of the gas in place has already been produced and the reservoir pressure have declined to around 10% of initial pressure.\u0000 In order to determine the location and quantity of condensate remaining in the field, dual porosity reservoir models were created with legacy data which replicated the naturally fractured reservoir. These models were history matched and gas injection simulation runs were performed in order to estimate the injection rates, reservoir pressure increase, field communication and potential for condensate re-vaporization and mobilisation theory at a variety of pressures. This theory was put to test and confirmed when SNOC recently performed a pilot gas injection project in one of its fields. A mixture of processed gas from the gas plant was injected and allowed to stabilise. The new mixture of injected and reservoir gas was reproduced to estimate the deliverability and ability of dry gas to vaporise the in-situ condensate. A fundamental challenge with SNOC was to determine the PVT property of the initial reservoir fluid from a surface recombined sample which made it extremely difficult to decipher the original fluid properties and history matching the reservoir model.\u0000 Utilising the field for gas storage can help elevate the reservoir pressure and increase the vaporisation of condensate, however since the field is naturally fractured it is susceptible to the injected gas fingering into a producing well. SNOC now plans to continue the next phase of the project to mature the modelling work, evaluate various sources of injection gas, understand the project uncertainties and establish the conditions required for the ECR project to be economically viable. This paper discusses the challenges, observations and its conclusion through the pilot gas injection project and its impact on the decision making for large scale implementation of enhanced condensate recoveries in the Middle East.\u0000 Maximizing field development objectives by combining various opportunities is the key to determining sustainability in the lower oil price environment. This paper demonstrat","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"76 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75157349","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":"Customer Technical Support: OEM Collaboration in a Digitalized World","authors":"Michael Werner, G. Bechini","doi":"10.2118/192623-MS","DOIUrl":"https://doi.org/10.2118/192623-MS","url":null,"abstract":"Wherever turbines and compressors operate — in oil and gas, power generation, or other critical infrastructure and industries — their uptime and availability are keys to profitability. Siemens Customer Technical Support provides operators of Siemens turbines, generators, and compressors with 24/7 performance monitoring, as well as early-warning support to flag KPI variances and anomalous conditions that could indicate trouble ahead. It delivers actionable intelligence for decision support to help them understand how to manage any performance issues until their next planned maintenance outage, increase availability and reduce the cost of unplanned disruptions. By doing so, we aim for combining the operational excellence of our customers and our OEM know how, utilizing the data connection as new way to communicate and collaborate with our customers. By using rule-based, physics-based and data-driven methodology, our diagnostic engineers are able to detect deviations of normal behavior and critical changes in health status of the machinery before they impact customer operation. In our Technical Support Centers embedded in the dedicated locations of our product lines, we process data of more than 1,700 units, servicing complete trains consisting of industrial and aeroderivative gas turbines, industrial steam turbines, turbo compressors, reciprocating compressors and gas engines, covering generator sets and mechanical drive applications. Finally, it will be presented how Siemens Customer Technical Support helps operators to increase availability, reliability as well as performance of their oil and gas and industrial rotating equipment. Showcases from the oil and gas industry with reference to generator sets and mechanical drive applications will also show the value in boosting customer proximity and operational efficiency.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"185 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75529244","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 Bit Technology: Transforming Tricone-Bit Drilling to New Levels","authors":"Y. A. Hammadi, A. Harbi, L. Hermawirawan, A. Aboulkheir, B. Akl, Reem Amer","doi":"10.2118/193178-MS","DOIUrl":"https://doi.org/10.2118/193178-MS","url":null,"abstract":"\u0000 This paper describes the step performance improvement of a 16’’ section in a UAE offshore application. Through close collaboration between directional drilling services, drill bits and operator, a 44% improvement in the section ROP from the field average was achieved. The novel solutions of bit and drive system and drilling practices which allowed for this improvement will be detailed in this paper.\u0000 A key contributor to this achievement was utilizing a new hybrid bit technology platform which incorporates the dual cutting mechanisms of both polycrystalline Diamond Compact (PDC) and tricone bits. This allows for more efficient drilling through bringing together the improved ROP performance of a PDC bit and the reduced torque fluctuations of a tricone bit. Where initially drilled by tricone bits, the application posed potential for performance improvement, which was to be explored with this bit and BHA solution. Continuous optimization of drilling parameters was essential to minimizing the vibrations and improving the overall drilling efficiency.\u0000 As a result of the proposed bit and drive system solution and the considerations in execution, the 4900ft long section was drilled in a shoe to shoe run, from surface to Fiqa formation. The unique compatibility between the bit design and the drilling motor allowed for exceeding the intended performance KPI set by the operator. The directional objectives were met as the well was precisely steered between offset wells with critical proximity, where the minimum ellipse separation expected was as low as 1.2ft. The new bit design was seen to not compromise the directional steerability as may be of concern with a PDC bit with a motor. The ROP achieved on the section was a 44% improvement from the field average. Given this being the first run from this new hybrid bit platform, this application still holds potential for further improvements upon design changes based on learnings from the first run. The outcome ultimately would be to take the conventional tricone drilling of this 16’’ section to a complete other performance level.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"480 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79956867","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}