Day 1 Tue, August 09, 2022最新文献

{"title":"Implementation of Well Delivery Process Application, A Success Story of Digitalization in Well Design Process","authors":"Veerawit Benjaboonyazit, Kazem Kiani Nassab, S. Buapha, Nithipoom Durongwattana, R. Garg","doi":"10.2118/209841-ms","DOIUrl":"https://doi.org/10.2118/209841-ms","url":null,"abstract":"\u0000 As a part of the company's digitalization project, the Well Delivery Process (WDP) software solution was successfully developed and launched in early 2021. By using this solution, engineers benefit from the project objectives like process standardization, well design quality, and well planning cycle time reduction. The WDP software consists of a series of integrated well delivery workflows including well design, drilling execution monitoring, and closeout reports within a single cloud-based platform. The system also provides users with many automation features such as well design rules validation, offset well analysis, risk analysis, automated calculations, and digital reports (drilling programs). Through this paper, we share our experiences and observations on the system development and implementation, and also challenges and limitations that we faced to roll it out successfully.\u0000 In our conventional practices before the digital transformation, drilling engineers had their individual practices/formats to perform the well delivery process using various applications and techniques. Computer applications were used to generate and compile a drilling program, but there was no standard way of performing this process. In situations where the design parameters and/or subsurface information change, engineers should have repeated the entire process to revise the design and/or the drilling program manually.\u0000 To standardize the process, minimize repetitive tasks, and provide engineers with all required digital tools, the first solution (a prototype computer program) was developed in-house to prove the concept. After multiple peer reviews and trials, we used the prototype program to specify user requirements for generating the WDP software solution. An agile methodology was utilized to engage all drilling engineers in each sprint of the WDP development phase to ensure that their requirements are fulfilled. Upon completion of the development phase, a comprehensive User Acceptance Test (UAT) was conducted followed by training sessions before the cut-off date for switching from the manual process to the WDP digital workflow. Switching from existing practice to a new way of work is always challenging especially when it comes to introducing new software. There was some resistance at the start-up period due to users' unfamiliarity with the software and also software bugs that were not found during testing periods and UAT. A support team was set up to ensure immediate action on users' requirements and any technical issues with the software. During the challenging transition period, all users were fully supported until make sure they are enough familiar with the system to complete the task effectively. The support team deployed hotfixes (bug fixing) as quickly as possible with no major impact on the drilling programs' timeline, monitored the system performance on daily basis, and gathered feedback for further improvements.\u0000 At present, the WDP is the primary syste","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"13 2 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116865358","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":"Development of Early Oil Well Cement Properties Using Laponite Particles","authors":"Abdulmalek Ahmed, A. Mahmoud, S. Elkatatny","doi":"10.2118/209845-ms","DOIUrl":"https://doi.org/10.2118/209845-ms","url":null,"abstract":"\u0000 The cement sheath is exposed to several loadings, which can possibly harm its key properties and impede its functions. These loadings become more significant at the early age of forming the cement sheath in which the properties of the cement are not completely developed. The objective of this work is to evaluate the changes in the cement matrix properties at the early stages of the hydration process for the cement containing laponite particles and compare it with the base cement. Laponite is a natural inorganic source containing mainly silicate. It is used as an additive to modify and enhance the rheological properties of many products.\u0000 Several cement samples with and without laponite were prepared and evaluated at four different curing times of 12, 24, 48, and 72 hours. Several cement properties such as porosity, Young's modulus, density variation and compressive strength were evaluated at each time. The results showed that the porosity of both cement samples increased with curing time, and the addition of laponite decreased the porosity of the cement samples. The addition of laponite particles also improves the elasticity of the cement as indicated by the decrease in Young's modulus. The early density variation of the cement was minimized when the laponite is used. The results of compressive strength indicated that the compressive strength of both cement systems increased with the increase of the curing time and the laponite-based sample had higher strength than base cement.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"28 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128090366","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 Application and Efficiency of Using a Single-Shot Circulating Valve During Hydraulic Fracturing Operations in the Event of Sand Screenout","authors":"T. Vo, Reawat Wattanasuwankorn, Wiwat Pattarachupong, Thum Sirirattanachatchawan, Kittithuch Hnuruang, Kitti Kanpiromkul, Apiwat Nadoon, Kanwisa Siriphruek, Pavin Pirom, Anan Thipprasert, Chatchai Paramart, Charin Chaisri, Panya Buatong","doi":"10.2118/209874-ms","DOIUrl":"https://doi.org/10.2118/209874-ms","url":null,"abstract":"\u0000 During most hydraulic fracturing operations, coiled tubing (CT) is used as a contingency option for well cleanup in the case of sand screenout. An alternative improvised solution is presented introducing a single-shot circulating valve into the frac string to help minimize additional resources related to CT procedures, thus reducing costs and enhancing operational performance. The tool is positioned above the retrievable frac packer to provide circulation capability to reverse out proppant sand without well intervention activities.\u0000 Setup, operating procedures, concept evaluation, and performance of the single-shot circulating valve used to reverse proppant sand from the frac string are discussed. A single-shot circulating valve in the frac string provides additional liquid flow pass for recovering excess sand inside the frac string to the surface. Intensive laboratory testing was performed to evaluate tool function in worst-case scenarios of a highly deviated well with proppant sand packed above the circulating ports. During field operations, activated pressure tolerance was defined by incorporating rupture-disk reliability and temperature decrement effects during hydraulic fracturing to help ensure the operating pressure did not impair the fracturing operation or well integrity. Lastly, a cleanout procedure was meticulously planned to help prevent pipe sticking situations caused by sand fallout in the annulus.\u0000 The single-shot circulating valve, typically deployed during drillstem testing (DST) operations, proved successful circulating out the proppant-sand column packed inside the tool during both laboratory testing and field operations. With precise hydrostatic pressure calculations, the burst pressure was reliable, meaning no premature activation occurred, and the rupture-disk burst within the designed surface pressure tolerance of ±400 psi. During reverse circulation, pumping pressure was maintained within an acceptable range (the maximum pumping rate across the circulating ports was 8 bbl/min) and no visual tool damage occurred. Deploying comprehensive engineering and operating procedures (e.g., defining the operating envelope to maintain a higher casing pressure than drillpipe pressure), the frac string and retrievable downhole frac packer were free of sand and successfully retrieved, even during a screenout scenario.\u0000 Based on the success of the prolonged two-year fracturing operations, the proposed approach is appropriate for fracturing using a single-shot circulating valve as the primary contingency equipment during screenout, replacing CT intervention for this application.\u0000 This alternative method resulted in improved safety and operational efficiency by eliminating on-rig CT operations when screenout pressure is trapped in the string in addition to significant cost savings attributed to eliminating the extra standby resources of a CT package.\u0000 This innovative approach, which applies functions of a downhole well-testing tool during ","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"9 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125001299","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":"Laboratory Study and Field Application of Salt-Tolerant Nano-Emulsion for Enhanced Spontaneous Imbibition Oil Recovery","authors":"Wenming Wu, J. Hou, Lixiao Xiao, Ming Qu, Weiju Wang, Infant raj Stephenraj, Yuchen Wen, Wei-Peng Wu, Tuo Liang","doi":"10.2118/209931-ms","DOIUrl":"https://doi.org/10.2118/209931-ms","url":null,"abstract":"\u0000 Spontaneous imbibition is an effective method to improve the oil recovery of tight reservoirs.The development and research of nano-emulsion provide a new technical direction for improving spontaneous imbibition oil recovery (SIOR) in tight reservoirs.The salinity has a significant effect on the properties and spontaneous imbibition of nano-emulsion, but the effect on the imbibition mechanisms is still unclear.In the paper, thelower nano-emulsion system with core-shell structures, called HS-LNE,is prepared by nano-emulsion dilution method.Afterwards,the properties and imbibition mechanisms of HS-LNE under different salinitiesare studied.Firstly,the particalsize andstability of the HS-LNE system are evaluated by centrifugation and spectroscopy. What's more, the interfacial tension (IFT), wettability,and adsorption experiments under diffierent salinitiesare carried out, and the salinity influences on the physicochemical properties of the HS-LNE system is systematically analyzed.At the same time, the SIORvariationlaw of the HS-LNE system under different salinitiesis comprehensively explored through static spontaneous imbibition experiments.The experimental results show that the HS-LNE system has excellent stability at high salinity. Moreover, as the salinity increasing, the IFT of the HS-LNE system decreased, and the wettability alternationincreased.However, the adsorption on solid interfaceswas not significantly changed and SIOR reached the highest value of 50.27% at the optimal salinity (50×103mg/L). Finally, the HS-LNE system with the optimal salinity was selected for the field test forpermeability enhancement and flooding in Well Gan 128 in Jilin Oilfield. The oil production was increased by 450 t after 5 months, with an estimated validity period of 24 months and a cumulative oil production increase of 1900 t.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"35 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123012280","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":"InSight: Corrosion-Wise Monitoring Tool Empowered by Robot Process Automation","authors":"Kittipat Wejwittayaklung, Nuttapon Piyakunkiat","doi":"10.2118/209849-ms","DOIUrl":"https://doi.org/10.2118/209849-ms","url":null,"abstract":"\u0000 InSight is the corrosion-wise monitoring tool that aims for facilitating the engineers in input data consolidation and corrosion analysis. By using the Robot Process Automation (RPA) digital tool and Business Intelligent (BI) tools, this time-consuming process will be dramatically expedited. Now, the project scope is only to analyze and monitor field integrity e.g., surface piping and downhole well tubing. However, it can be scaled up to other applications and business areas.\u0000 RPA on the engineering software requires detailed steps and layers of commands. Developing the new RPA engine is a more flexible and generic way to manipulate the engineering software. The well test data stored in the database was linked to the on-premises server in which the RPA engine and corrosion simulation were deployed and installed. After daily data arrived, the RPA will be automatically run and transfer the result of the corrosion analysis back into the database. BI tool then pulls the data from the database and visualizes the analysis result, also has an alarm function to responded parties.\u0000 InSight has been developed by PTTEP since 2020. RPA engine for two corrosion simulations was completely deployed namely PRECORR and OLI. Now running corrosion simulation is easy with just one click and over a thousand cases can be run within a day. Generally, this corrosion simulation via RPA is 9 times faster than the human. The engineers will then have more time to focus on data quality verification and the data analytics of the simulation result. The tool is quite flexible for the users. The data pulled from the daily database can be manually selected and corrected. In addition, a sensitivity analysis can be designed. Likewise, the result visualization can be customized. Subsequently, the actual field corrosion logging data or the laboratory corrosion tests can be tied in for the model calibration. Moreover, the tool can add more corrosion simulation software with additional effort. However, the main users are still improving the tool performance throughout the real use cases.\u0000 This RPA engine will change the world of routine corrosion simulation and monitoring. Also, it can be supplied to any routine engineering simulations. For this project, the well will be produced safely with close monitoring of corrosion and an alarm system.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"55 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126618909","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":"Explore Beyond Boundary – New Record to Reduce Emission and Drilling Cycle Enabled Through Innovative Technologies and Project Management","authors":"Feng Liu, Dongdong Han, Liangwei Xiang, Dawei Li, Guojin Hu, H. Zhao, Jiejing Gong, Xin Zhou, Shuai Wang, Nan Huang, A. Abbasgholipour, Chulakorn Yosakrai","doi":"10.2118/209842-ms","DOIUrl":"https://doi.org/10.2118/209842-ms","url":null,"abstract":"\u0000 Under the background of optimizing project costs and decreasing carbon footprint, CNOOC launched a campaign strategically to explore new offshore records. This paper records how the pilot project of this campaign achieved remarkable success to dramatically decrease operation cycle time and reduce drilling waste discharge with the help of technological innovation and advanced project management.\u0000 The innovation to improve drilling efficiency starts from well designing phase. Wellbore geometry is optimized and downsized to smaller hole size to improve drilling rate and reduce drilling waste. A series of innovative modifications are made on both the rig operating equipment and the work process to reduce the operation time. Novel technologies are utilized to reduce drilling cycle time including industry's first definitive dynamic survey-while-drilling service, realtime drilling intelligence service, pulse neutron generator (PNG) enabled multi-function logging while drilling (LWD) platform, and so on. Bit and motor are both optimized to increase drilling speed. To reduce the waste discharge during drilling and completion, a fully closed zero discharge system is employed. Flawless project management also played vital role in the project success.\u0000 Totally 23 wells are drilled for this pioneer project. 269.80 days are saved compared with plan and drilling efficiency is improved by more than 58%. Wellbore geometry optimization saves 111.63 days drilling cycle time and reduces 3189 tons waste. 25.94 days are saved by utilizing advanced measurement while drilling (MWD) tool and LWD technologies. More than 14 days are saved by innovative modification on the rig equipment. At least 7 days are saved through optimizing the work process. With the fully closed zero discharge system, 2414 cubic meters drilling fluid is reused and 7040 tons cutting are processed. This project breaks several drilling records in CNOOC.\u0000 The novelty of this paper is to provide experiences of utilizing most up-to-date technologies and innovative systematic approach to reduce the drilling cycle and carbon and waste discharge.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"77 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124106065","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":"Stiff String Torque and Drag: Choosing a Realistic Tortuosity Model","authors":"B. Nobbs, Christophe Plee, N. Dao","doi":"10.2118/209846-ms","DOIUrl":"https://doi.org/10.2118/209846-ms","url":null,"abstract":"\u0000 Selection of the correct tortuosity model is critical when performing a pre-planning stiff string torque and drag analysis. Various tortuosity models exist in the literature however selection and calibration can be complicated. This paper presents a methodology to aid in selecting an appropriate tortuosity model as well as real case studies.\u0000 The goal is to apply a suitable tortuosity to a planned trajectory that will mimic the expected tortuosity along the wellbore. Depending on the directional drilling driving system employed, the trajectory can be smooth or very tortuous with significant additional local doglegs. Overall, the effect of standard tortuosity models on a run-in-hole (RIH) analysis using a stiff string torque and drag model will be investigated. Industry standard tortuosity models such as sinusoidal, random, random with dependent azimuth and helical will be investigated to help identify when they are appropriate depending on the directional driving system employed.\u0000 In today's high-cost and complex 3D wells, simulations using smooth planned trajectories together with conventional soft-string torque and drag models have shown its limits in anticipating bottom hole assembly (BHA), casing or completion strings lock-up events. Hence, new methodology shall be introduced to better predict field observations. This methodology shows that the applicable tortuosity model may change depending on the directional driving system used. The drilled path or a motor, with a slide-rotate pattern, may be significantly different to that of the cyclical path drilled by a rotary steerable system (RSS). The case study shows that the additional tortuosity that was generated by the directional driving system had a significant effect on predicted hookload margin as well as elevated forces and stresses along the liner. The stiff string torque and drag and buckling model can analytically calculate the contact points which may vary significantly, both axially and radially, in a tortuous wellbore. Ultimately the selection and calibration of an applicable tortuosity model is necessary when performing a robust stiff string torque and drag analysis.\u0000 This ability to correctly apply a tortuosity model in preplanning reduces the risk of BHA, casing and/or completion strings getting stuck or locked-up when running in hole, paving the way for a reduction in non-productive time (NPT) and loss of equipment.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"27 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122333788","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":"Gulf of Thailand 4-String Well Design Transformation Using MPD System – Cost Saving, Operational Challenges and Learnings","authors":"Harpreet Kaur Dalgit Singh, E. Sammat, Thakornpol Kleawyothatis, Kittikun Niracharopas, Kazem Kiani Nassab","doi":"10.2118/209911-ms","DOIUrl":"https://doi.org/10.2118/209911-ms","url":null,"abstract":"\u0000 Gulf of Thailand (GoT) or Gulf of Siam is mainly offshore development gas wells in Thailand. Well C and well H were originally designed with GoT 4-string standard template. However, Managed Pressure Drilling (MPD) solution was then selected to save one (1) casing string provided that the maximum expected formation pressure to be within the range of 1.46-1.50SG as per geological prognosis. Both wells were drilled to plan TD with 3-casing strings as planned to result in a cost-saving from the design transformation (4-strings to 3-strings) using the MPD system.\u0000 There is always a risk of lost circulation and ballooning in intermediate/high-pressure wells (Pore Pressure (PP) > 1.45SG) when drilling conventionally with 3-casing strings (instead of GoT 4-string standard design). Required high mud weight imposes an overbalance during drilling and tripping operations that exceed formation integrity at shallower depths below the 7\" casing. MPD is a proven technology for maintaining Constant Bottom Hole Pressure (CBHP) that enables precise control on wellbore pressure to mitigate ballooning and kick/loss hazards, narrow margin drilling window, and formation pressure uncertainties. The 6-1/8\" hole sections of both wells were drilled with the MPD technology to mitigate the loss of circulation and ballooning while drilling.\u0000 MPD system worked for this project to drill the wells to TD successfully according to the plan and without any major issue. The MPD solution enabled drilling with the lowest and safest underbalanced mud weight to allow a reduction in Bottom Hole Pressure (BHP) and consequently eliminated ballooning while drilling. Surface back pressure (SBP) on connections was increased (compared to the plan) based on connection gas reading caused by pore pressure uncertainties. MPD dynamic formation integrity test (DFIT) and static pore pressure tests (PPT) have established a baseline for heavy kill mud weight estimations and displacing before tripping out of the hole. Observations and learnings from well C confirmed the study’s preliminary conclusions that the 4-strings transformation is quite challenging for PP greater than 1.55SG, and 4-string transformation is not recommended if PP exceeds 1.60SG. The wells were completed with 3-casing strings however, no NPT related to well design and MPD was encountered. The technology was proven and allowed to drill the well with 3-strings design. The solution can save some cost in intermediate pressure wells (1.46-1.54SG PP), and it is proposed for the next trials with more focus on wellbore conditioning and tripping practices.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"74 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131398253","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":"Strategic Reservoir Characterisation Manoeuvre in a Clay Sensitive, Pressure-Depleted and Geomechanically Complex Gas Reservoir in Offshore Peninsular Malaysia","authors":"S. Zulkipli, Munawar Abdul Hamid, David Nanlung Dangfa, S. Han","doi":"10.2118/209902-ms","DOIUrl":"https://doi.org/10.2118/209902-ms","url":null,"abstract":"\u0000 Acquiring subsurface data in a highly unstable and geomechanically complex formation pose unusual challenges to adequately characterize the reservoir from production and completion perspective. The traditional way of acquiring data through LWD or wireline logging might be operationally constrained by severe hole break-out, mud losses and high differential sticking due to pressure depletion across the reservoirs. This condition warrants a specific and critical approach to optimally design the data acquisition plan to minimize subsurface uncertainties to meet the gas production target from the field. This paper will highlight customized techniques to successfully acquire good quality of subsurface logging and pressure data, technical and operational considerations involved and some of the best practice applied to operate within the threshold limit amidst the time-dependent hole instability culprit.\u0000 Detailed technical plan, rigorous pre-job simulation and sensitivity analysis set the high tone to acquire critical subsurface log and pressure data prior to completion. Customizing LWD drilling dynamic parameters such as mud circulation rate, real time data transfer rate, pressure drawdown and build-up time, controlling the logging speed in ROP and optimizing the mud design are among the approaches taken to obtain fit-for-purpose data in a very narrow operating limit amidst the borehole instability issues. Acquiring real time image from LWD density tool enables fracture and break-out evaluation validating the existing geomechanical model in this field and enhance the understanding of causes for hole instability issues leading to real time well trajectory optimization and updating. Theoretically, open hole log data can be also complemented by cased hole pulsed neutron and production logging acquisition to formulate reservoir properties, gas water contact and estimated shut-in reservoir pressure through prolific log processing methodology and interpretation procedures.\u0000 Post data acquisition activities along the problematic reservoir interval and incorporating all the interpretation outcomes, the reservoir connectivity and pressure communication are confirmed throughout the field area. Even though the main target reservoirs in the newly drilled well could not be completed and produced due to operational issues, the case presented in this paper will provide valuable lessons learned in designing and operating a well in the highly complex geomechanical area and strategizing data acquisition program to minimize the subsurface uncertainties. Best practices in customizing LWD open hole and wireline cased hole data acquisition to fully characterize the formation including downhole CO2 gas presence set the pioneering guideline in this region and become the critical benchmark for future well operation.\u0000 In conclusion, securing adequate and reliable subsurface data in a highly unstable and geomechanically complex formation will justify for a strategic approach a","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127665757","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":"Digitalization and Automation of the Planning and Execution of Well Construction Process","authors":"A. Ruzhnikov, E. Echevarria, Choon Kit Phan","doi":"10.2118/209883-ms","DOIUrl":"https://doi.org/10.2118/209883-ms","url":null,"abstract":"\u0000 Well construction process can be presented as a set of the routine and repetitive actions which should be repeated at the planning, execution and evaluation stages. The manuscript describes how in the effort with major operating company the well planning stage was converted to a complete digital path; and how the digitalization of the planning was further transferred to the automated execution.\u0000 Planning a well normally done with different computer software, where the data gathered from different engineering software should be input, as well as required drilling fluid, cementing and directional job plans and limits etc., followed by the written operational sequence. In the reviewed case all the planning was shifted to the cloud environment, including all simulations and reviews, where no \"merge\" of the data was required. All the required simulations are performed automatically, flagging those with the results out of the limit. The operational steps were detailed, and further connected to the rig Variable Frequency Drives (VFD) system, where multiple operations started to be performed in automatic mode, without any intervention from the rig crew (like survey, drilling parameters automatically adjusted to the sock and vibration, stick and slip, seeking for the best rate of penetration, driller's tasks while drilling, backreaming of stand etc.).\u0000 The implementation of the digital planning allowed to align all stockholders involved during design stage, minimize human mistakes, and significantly decrease the planning time. The noticeable side effect is absence of any physical paper and as well as higher transparency during preparation. At the execution stage at the begging of the implementation the main benefit came from the standardization of the practices at the rig, what lead to absence of discrepancies. It further resulted in delivery of the all the wells under the same time with very minimum difference. And the final positive result came from the absence of any major service quality event (like stuck pipe) during automated operations. As of now the different levels of digitalization are implemented in 16 rigs, with further current expansion.\u0000 The manuscript provides the novel information on the digitalization and automation of the well construction process. The explained methodology can be implemented at any project worldwide.","PeriodicalId":385340,"journal":{"name":"Day 1 Tue, August 09, 2022","volume":"37 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-08-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127790054","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}