Day 2 Mon, February 20, 2023最新文献

{"title":"Anisotropic Poroelastodynamics Solution and Elastic Moduli Dispersion of a Naturally Fractured Rock","authors":"Chao Liu","doi":"10.2118/213366-ms","DOIUrl":"https://doi.org/10.2118/213366-ms","url":null,"abstract":"\u0000 In this work, the theory of anisotropic dual-porosity dual-permeability poroelastodynamics is used to simulate the responses of pore pressure, displacement, and stress of a fluid-saturated transversely isotropic naturally fractured cylindrical rock sample. The sample is subjected to a harmonic loading with a constant displacement amplitude at one end. These solutions are then use d to calculate the elastic moduli dispersion of the rock sample. A transversely isotropic water-saturated rock sample is selected as an example to demonstrate the simulation and the mechanisms of the dispersion due to the coupled motions of the rock matrix and fluids in pore spaces and fractures. The effects of material anisotropy on the poromechanical responses and the elastic modulid dispersion of the rock sample are presented. We also show excellent matches between the simulation and laboratory measurements of the dynamic Young's moduli of two shale, one clay, and three sedimentary rock samples.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"38 7 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116800860","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":"Towards Real-Time Bad Hole Cleaning Problem Detection Through Adaptive Deep Learning Models","authors":"P. Nivlet, K. Bjørkevoll, Mandar V. Tabib, J. O. Skogestad, B. Lund, Roar Nybø, A. Rasheed","doi":"10.2118/213643-ms","DOIUrl":"https://doi.org/10.2118/213643-ms","url":null,"abstract":"\u0000 Monitoring of Equivalent Circulating Density (ECD) may improve assessment of potential bad hole cleaning conditions if calculated and measured sufficiently accurately. Machine learning (ML) models can be used for predicting ECD integrating both along-string and surface drilling measurements and physics-based model (PBM) results, even though their generalization is often challenging. To remediate this generalizability issue, we present an adaptative predictive deep-learning model that is retrained with new measurements in real-time, conditionally that the new measurements are not detected as anomalies. Past ECD measurements, corresponding values predicted by a 1D PBM and other drilling measurements are used as input to a deep learning model, which is pretrained on historical drilling data without any hole cleaning problem. This model has two components: an anomaly detector, and a predictor. In this paper, both components are based on combinations of Long Short-Term Memory (LSTM) cells that allow (1) to account for data correlations between the different time series and between the different time stamps, and (2) generate future data conditioned to past observations. As drilling progresses, new data is proposed to the anomaly detector: if the network fails to reconstruct them correctly, an alarm is raised. Otherwise, the new data is used to retrain the models. We show the benefits of such an approach on two real examples from offshore Norway with increasing complexity: For the first one, with no major drilling issue, we simply use ECD from the PBM to predict ECD ahead of the bit. The second example had multiple issues linked with mud loss and poor hole cleaning. For this latter case, we used additional topside measurements to better constrain the ECD prediction.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127131698","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":"Unmanned Rotating Equipment for Normally Unattended Installations (nui)","authors":"Davide Bartolini, Daniele Porciani, Alessandro Leto","doi":"10.2118/213596-ms","DOIUrl":"https://doi.org/10.2118/213596-ms","url":null,"abstract":"Offshore Oil & Gas operators are facing unprecedented challenges due to need to reduce OPEX while at the same time operating in harsh/remote environments with an ever-top attention on Safety and Carbon Footprint reduction.\u0000 Technology innovation, especially on digitalization and control, is a game changer that gives customers the opportunity to adopt low manned or totally unmanned solutions while avoiding any compromise on Cybersecurity standards.\u0000 Developing unmanned trains for power generation and compression requires the introduction of different solutions: hardware and control system modifications, surveillance systems, digital services for advanced degradation monitoring.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"84 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124976488","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 Novel Engineered Drilling Solution using a Sourceless Geosteering Bottomhole Assembly to Deliver the Longest Extended-Reach Well in a Carbonate Reservoir, Onshore Abu Dhabi, UAE","authors":"W. Fares, Ashim Dutta, R. Reddy, Moahmed Baslaib, Ayman El Shahat, L. Cardozo, Mohamed Abdel Meguid, M. Nasrallah, Muhammad Mubeen, A. Aki","doi":"10.2118/213713-ms","DOIUrl":"https://doi.org/10.2118/213713-ms","url":null,"abstract":"\u0000 To develop a mature onshore carbonate field in Abu Dhabi and reduce the footprint and cost, an artificial island has been built in shallow water that can accommodate drilling rigs and extended-reach wells. This paper presents a case study of the longest onshore well drilled in Abu Dhabi. Planning to drill such a deep well starts long before execution, using offset well data and extended-reach drilling (ERD) engineering. There were formation and reservoir challenges due to the uncertainty in the earth model in the horizontal section of the well. Hence, it was very challenging to maintain contact with the thin reservoir intervals, without approaching the boundaries. In addition, the limited power available to drive the drillstring and maintain circulation drove the ERD engineering team to find optimum solutions, including drillstring and bottomhole assembly (BHA) design. Furthermore, there was a known risk of differential sticking, which meant that the use of radioactive sources in the BHA was undesirable. The well was planned to be drilled in two runs, using nuclear measurements in the first run and non-nuclear measurements in the second. A well-placement methodology and workflow was developed and integrated with the geological understanding of the target layer. Analysis of offset horizontal wells resulted in the delivery of an optimized BHA design, including careful selection of logging-while-drilling (LWD) technologies, to mitigate the geological challenges. The BHA also included a new generation of intelligent, fully rotating, high-dogleg, push-the-bit rotary-steerable system, to geosteer the well in the thin target layer while maintaining the planned target trajectory with minimum borehole tortuosity by means of real-time drilling optimization.\u0000 The extended-reach horizontal section was drilled successfully, and the geosteering objectives were achieved with 100% reservoir contact over a 20,000-ft interval, targeting a thin carbonate layer and overcoming the complex geological environment. The well was drilled to a record depth of 32,300 ft. The new intelligent rotary steerable system with automatic cruise control helped to eliminate any well-profile issues, minimize wellbore tortuosity, and maintain aggressive drilling parameters. The nuclear and non-nuclear LWD measurements, including NMR, helped to reinforce understanding of the reservoir properties along the entire section.\u0000 This success has opened the door for drilling more challenging wells. In addition, it has proved that proper planning and execution can shift the boundaries further and gave confidence to drill even deeper.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"4 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125300406","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":"Improved AMD Nanosheet System to Increase Oil Production Under Harsh Reservoir Conditions","authors":"D. Cao, M. Han, Mohanad M. Fahmi, A. AlSofi","doi":"10.2118/213888-ms","DOIUrl":"https://doi.org/10.2118/213888-ms","url":null,"abstract":"\u0000 Amphiphilic molybdenum disulfide (AMD) nanosheet is a novel flake type Nano material, which is different from the widely used particulate Nano material, for increasing oil production. Most of the current researches and applications of nanosheets were for low temperature and low permeability sandstone reservoirs. This work investigated an improved nanosheet system for permeable carbonates at harsh reservoir conditions.\u0000 AMD nanosheet sample was a concentrated black liquid with flake size about 80*60*1.2 nm. The features in a high salinity water (HSW) and high temperature were characterized by compatibility test, interfacial tension (IFT) test, emulsification test, and phase behavior test. The potential for increasing oil production was evaluated by micromodel displacement tests. The micromodel was treated to oil-wet to simulate the wettability of carbonates. The performances of initial sample and improved sample by a cationic surfactant were compared.\u0000 Initial AMD nanosheet sample was not compatible with HSW at 95 °C. A cationic surfactant significantly improve the compatibility. IFT of 50 mg/L nanosheet with a light oil was 0.46 mN/m at 25 °C. IFT of The improved system with the surfactant decreased to 0.21 mN/m at 90 °C. The increase of nanosheet and surfactant concentration resulted in an IFT increase. Although IFT was not ultra-low, nanosheet had strong interfacial activity on oil-water interface even at low concentration. Nanosheet-only produced much stable emulsion than surfactant-only. Mixing nanosheet and surfactant increased emulsion stability slightly. Phase behavior results demonstrated that surfactant improved the hydrophilic and lipophilic balance of nanosheet to produce Winsor III type microemulsion. In core flow testing, the nanosheet alone injection partially plugged the core plug with relatively high adsorption/retention. Adding the surfactant improved the migration and reduced adsorption of nanosheet in porous media. Micromodel displacement test showed that improved nanosheet system at low concentration of 50 mg/L increased oil production by more than 20% after water flooding at both ambient temperature and reservoir temperature at 95 °C.\u0000 This study investigated a more efficient material with same dimension as oil-water interface compared with surfactant or particulate Nano materials. An improved nanosheet system was developed for carbonate reservoirs under harsh conditions.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"10 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125389895","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":"Maintaining Hydraulic Fracture Conductivity Under High Stresses through Consolidation with DAP","authors":"M. Desouky, M. Al-Jawad, Murtadha El-Tammar, Khalid El-Ruwaili","doi":"10.2118/213670-ms","DOIUrl":"https://doi.org/10.2118/213670-ms","url":null,"abstract":"\u0000 Acid fracturing creates conductive fractures in carbonate reservoirs through acid-rock dissolution. However, over-etching or stimulating weak carbonate formation could result in a fast decline of fracture conductivity. In addition, most models in the literature showed that rock strength has an exponential impact on fracture conductivity. This work conducted experiments to mitigate this problem through rock strengthening with diammonium phosphate (DAP).\u0000 Different fracture surfaces were tested using the ACM-3000 acid fracture conductivity system to compare the conductivity of intact samples with the treated ones. The fracture conductivity of 4 pairs of weak Austin chalk samples (7in × 1.34in × 3in) with flat surfaces was evaluated by flowing nitrogen gas (200-350 cc/min) at increasing stresses up to 1,500 psi. Half of the samples were kept intact to represent the control group to which treated samples were compared. The treatment consists of saturating vacuumed chalk samples with 1M DAP for 72 hrs at pressure and temperature of 1,000 psi and 75°C, respectively. In addition, the surface hardness of the samples was measured pre-and post-treatment, and conductivity measurements were performed to evaluate the treatment effect on the samples.\u0000 The chalk samples used in this study are naturally weak with low average surface hardness (i.e., 3 GPa compared to 15 GPa for Indiana limestone). However, the DAP solution could significantly enhance the surface hardness of soft chalk up to almost 3.5 times its original value. The chalk hardness increase reduced the normal deformation and increased the yield stress of the treated samples. The untreated sample exhibited lower endurance to loading and developed cracks at lower stresses. Also, the results showed that the normalized conductivity of the treated flat samples is at least double the untreated ones. The chemical treatment makes the chalk stiffer with less deformation when stressed, which leads to enhanced conductivity at higher stress.\u0000 In this paper, an additional stage is suggested in acid fracturing to harden the surface of carbonate rocks chemically after acid injection. Successful application of such treatment in the field can extend fracture life and substantially reduce the need for re-fracking jobs.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"33 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115999628","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":"Transforming Challenges into Opportunities to Design Fit for Purpose Long Term Polymer Injectivity (LTPI) Pilots in Umm Gudair Minagish Oolite Reservoir, West Kuwait","authors":"Mohammad Yunus Khan, Dawood S. Kamal, H. Al-Mayyan, A. Pradhan, Satish Kumar Eadulapally, M. T. Al-Murayri","doi":"10.2118/213404-ms","DOIUrl":"https://doi.org/10.2118/213404-ms","url":null,"abstract":"\u0000 Umm Gudair Minagish Oolite is a highly heterogeneous reservoir with intermittent micritic units forming low permeability barriers to fluid flow. Based on screening/lab study, the polymer or surfactant-polymer flooding was proposed using normal 5 spot injection pattern. KOC decided to test only polymer flooding because of cost considerations. This study is to design fit for purpose long-term polymer injectivity (LTPI) pilot using produced water (salinity 230000ppm) with the objectives of testing injectivity, adsorption, breakthrough, resistance factor and response time within 6-12 months.\u0000 Numerical simulation and economic modelling was used for this evaluation to explore various novel strategies. Various parameters were optimized to design Fit for Purpose LTPI pilot configurations using high salinity produced water. The laboratory experiments were conducted in conjunction with reservoir simulation to confirm the technical viability of polymer flooding using high-salinity water. In this study, we discuss existing challenges and how the same was transformed into opportunities by optimizing various parameters such as number of wells, well spacing, well location, perforation layer for injectors and producer and the economics to meet pilot objectives.\u0000 The simulation results show that normal 2-spot injection pattern (2 injectors and 1 producer) with 80m well spacing and perforation in B-zone is a suitable solution for LTPI pilot within given time. Based on the above plan, one injector was drilled near the existing producer. The recent gyro survey demonstrated shifting of the sub-surface locations of both the producer and injector, thereby altering the well spacing. Further simulation incorporating the new locations indicated that the pilot would not meet the objectives within the piloting duration of 6 months because of shifting. Surface constrains hindered the shifting of drilling location for the second injection well to maintain 2-spot injection pattern. To overcome this challenge, additional simulation works performed to plan and drill the second injector well near another existing producer at 80m well spacing in a different area to test different rock types. Both LTPI pilot designs show higher incremental cumulative oil over water flood, faster polymer breakthrough (∼1 month), faster polymer response and oil peak within 6 months. In addition, using high salinity produced water for polymer flooding is expected to reduce piloting cost and increase operational efficiency by reducing operational problems associated with treatment and handling of less saline water.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"26 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122359566","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":"Correlation of Borehole Images in Conductive and Non-Conductive Muds to Understand Carbonate Heterogeneity: Case Study from Sichuan Basin, China","authors":"K. Hou, Zuoan Zhao, Gensheng Ni, G. Sultan, Bo Liu, Tianhua Zhang","doi":"10.2118/213230-ms","DOIUrl":"https://doi.org/10.2118/213230-ms","url":null,"abstract":"\u0000 The heterogeneous carbonate reservoir is the most important exploration target in Sichuan basin. It is challenging to identify the potential flow units in the tight carbonate reservoir. High-resolution borehole resistivity image can reveal the dissolution features such as vugs or fractures in the pay zone. Operators in Sichuan Basin have acquired lots of borehole resistivity image using water-based mud imager in key exploration wells to identify potential reservoir. The oil-based mud has become increasingly popular in exploration and development because it reduces complex drilling practices reducing drilling costs. The new generation oil-based imager is used in these new wells. The borehole resistivity image can be obtained from both OBM (oil base mud) imager and WBM (water base mud) imagers. It is important to understand the response differences through the comparisons between different borehole imaging technologies in the same wellbore. The objective of this study is to understand the responses and refine the rule of oil-based mud borehole image interpretation in tight carbonate reservoir.\u0000 The operator has logged both WBM and OBM imager in the same wellbore at different times. The WBM resistivity image is acquired in water-base mud conditions in the beginning. Then drilling fluid system was changed to OBM, and 200 meters were drilled further in the borehole. Finally, the OBM imager was logged in the hole. A comparison between the WBM resistivity images and OBM resistivity images are carried out. Increased understandings of the image log responses in this vuggy or fractured carbonated reservoir were obtained.\u0000 The borehole resistivity image from WBM and OBM imager is highly correlatable over most of the logging interval as they both show similar resistivity response (bright / dark) on both images for the same geologic feature. The new generation OBM resistivity imager is proven to have similar applications as the WBM resistivity could offer. In fact, the OBM borehole images has higher resolution than the WBM borehole image in most of the intervals, especially in high resistivity formations. It was found that the responses of vugs or fractures can be interpreted slightly different in some intervals. Only the unfilled vug will have resistive response in OBM image while it will be very conductive in the WBM image because it was invaded by the resistive or conductive mud. The responses of induced fractures or natural fractures will be slightly different, which is influenced by formation conditions such as Rt/Rm. The induced fracture could be conductive or resistive under different logging conditions.\u0000 This case study improved the understandings of the OBM imager response in tight carbonate reservoirs. These observations can be used as a reference for borehole image interpretation in similar reservoirs.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"66 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"122673883","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":"De-Risking Upper Cretaceous A Formation Production by Joining Multiple Technoologies in 3D Space","authors":"E. Cazeneuve, Y. Bouzida, V. Smirnov, Maniesh Singh, J. Ahmed, Nepal Singh, R. Celma, Sami Sheikh Alawi Shehab","doi":"10.2118/213355-ms","DOIUrl":"https://doi.org/10.2118/213355-ms","url":null,"abstract":"\u0000 Realistic geological characterization is crucial for the development of carbonate reservoirs specially to overcome some challenges related to Early Water Break Through (EWBT) like those observed in the Upper Cretaceous ‘A’ Formation. The complexity of the depositional, diagenetic, and structural history created unpredictable connected pathway with the aquifer. Therefore, having suitable conceptual geological models tied to well data helps to better anticipate their occurrence and extension to plan for suitable well placement, a completion design, and optimize the production.\u0000 The objective in this case study was to assess the Deep Shear Wave Imaging (DSWI) technology that can bridge the scales between well Borehole Image (BHI) and conventional Seismic to identify sub-Seismic features up to 100ft away from the well bore. A statistical evaluation of the BHI was used as a reference for this DSWI assessment. Then the result was compared with Seismic coherency to assess the value of the combined data.\u0000 This cross-discipline integration in 3D from different data measurements with a variety of scales by order of magnitude difference between them (Well and Seismic), has allowed to build a conceptual model of the near wellbore region up to 90ft and predict five significant fault zones that are susceptible of connecting with aquifer. Dynamic data will be used in the second phase of the project such as (liquid rate, water breakthrough and tracers) to analyze their contribution to the EWBT and refine/enhance the interpretation.\u0000 The way forward is to apply a similar workflow to other wells in the field, to gain a solid understanding of the sub-seismic architecture of the subsurface and hence timely optimize the setup of Inflow Control Device (ICD) design used to mitigate EWBT.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"105 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114268880","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":"Integration of Geosteering into an Automated Wellbore Placement System, Possibilities and Challenges","authors":"D. Holbrough, M. Forshaw, S. Wessling, Saskia Idzerda, R. Gelfort, S. Austin","doi":"10.2118/213714-ms","DOIUrl":"https://doi.org/10.2118/213714-ms","url":null,"abstract":"\u0000 The benefits of geosteering for accurate wellbore placement in reservoirs are well documented, with an emphasis on comprehensive reservoir mapping capabilities and related well path adjustments. Similarly, drilling-related processes such as well re-design, proximity scanning, and downlinking are important. The integration of geosteering and drilling processes adds complexity and challenges to designing automated wellbore placement systems. Automated systems need to contain sufficiently robust technologies and algorithms to avoid unintended and frequent exceptions. Equally, the human element must be considered to design an automated system with a great user experience. To gain user acceptance, an automated system must have the characteristics of predictability, transparency, adaptability, and automation levels that are validated prior to utilization. Without this, the result will be wellbore misplacement by engineers who blindly trust immature automated systems.\u0000 This paper provides an overview of processes and tasks within a comprehensive wellbore placement system, including the directional drilling and geosteering services as used by stakeholders who own well placement execution. We will provide an overview of the potential of automation and pitfalls to be avoided. The experience of many expert engineers from complementary disciplines has been used to develop a comprehensive concept as a framework to implement an automated wellbore placement system.\u0000 The paper also provides an analogy to the automotive industry which has developed reliable and robust systems for navigation, lane and speed control over the last few decades. The comparison highlights a fundamental difference to the petroleum industry of having multiple stakeholders involved in the process of wellbore placement. Consequently, communication between all the stakeholders during operations, notably proposals and approvals, must be designed into the system from the beginning.\u0000 Automation concepts to achieve great user experience are demonstrated on components of a wellbore placement process, including the illustration of lessons learned from recent development initiatives. Based on the demonstration, we conclude that an iterative development process is essential to ensure acceptance by the user community.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"42 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125489969","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}