Day 2 Mon, February 20, 2023最新文献

{"title":"NGL Operation Strategy Using Predictive Analytics","authors":"Abdulaziz Qurashi","doi":"10.2118/213290-ms","DOIUrl":"https://doi.org/10.2118/213290-ms","url":null,"abstract":"\u0000 Oil & Gas is a data-rich industry which is prime for data-driven and decision making. The significant growth witnessed in the digital transformation field and the new era of the industrial revolution 4 (IR 4.0), is a direct result of the need within the industry to utilize the large amount of data to make better decisions, improve operation strategy, plan better for preventive maintenance (PM), and process improvement.\u0000 The uncertainty associated with estimating the incoming feed gas rate to NGL plants has resulted in deviation from optimal compressor recycle rate, missed opportunities of meeting planned PM and imposed urgency during operation. Utilizing machine learning algorithms, namely regression and decision tree model, the incoming feed gas can be predicted which result in the machine learning algorithms which results in the identification of the optimum number of running trains and recycle rate required for efficient operation.\u0000 NGL-Operation Planner (NGL-OP) is the outcome of utilizing ML algorithms which provides the ability of predicting incoming feed gas, identifying optimum number of running trains required as well as estimating the optimal recycle rate. Adopting this approach is a new and strategical way to plan NGL operation. The developed tool also has the ability to advise whether to shut down, maintain existing operation or starting-up a new train.\u0000 The implementation of the model resulted in a significant improvement in NGL operation. The improvement includes fuel gas consumption reduction of around 449 MMSCF/Year which resulted in a significant cost saving, reduction in emissions around 27 M tons/year, and 10% reduction in operating unnecessary running trains. These savings have been achieved through the utilization of the NGL-OP to minimize uncertainty and improve our planning strategy.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"23 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":"121790339","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":"Artificial Well Engineering Intelligence (AweI): Is It Drilling Engineer's Dream or Driller's Nightmare?","authors":"Robello Samuel, K. Kumar","doi":"10.2118/213686-ms","DOIUrl":"https://doi.org/10.2118/213686-ms","url":null,"abstract":"\u0000 Applying artificial intelligence (AI) is exceedingly difficult for drilling operations as the system is overly complex and dynamic. As a result, more comprehensive domain-general engineering mapping, also known as \"artificial well engineering intelligence,\" is required to predict operating parameters and problems with reasonable accuracy. This paper presents a detailed overview of engineering models that are interconnected in the form of microservices to provide a more logical solution as the well is drilled. It draws out some important findings and discusses ways that results can be infused with the work on explainable artificial engineering intelligence in realtime. The results argue the logical reasoning and mathematical proof.\u0000 Drilling Engineer–Driller–Rig system interaction through AweI with interconnected subdomains requires tighter integration between various engineering models. To some extent, tractable abstract knowledge at the human level is derived from analytical reasoning through engineering models. Various engineering models are connected in the form of microservices, which can be called any number of times when the optimization is carried out. The results are transferred for physical actions either to the driller or control as set points. The method presented does not claim to address all the issues as a whole. This methodology attempts, however, to present a coherent adaptive model that provides more transparency to the algorithms that can be used as operational parameters for the driller.\u0000 The analysis results have shown that the convergence was very quick in obtaining an optimal solution and the predictability in the test wells has shown the best solution results under uncertainty. It has also been found that the results provide reasonable threshold values when increased data is used as the well is drilled. As long as the driller stays within the operational region, the results have shown that the operating parameters are satisfying and good enough for the desirable outcome. In other words, a near-normal engineering solution is achieved.\u0000 The two major interacting bottlenecks observed in the study are (1) the absence of domain-expertise and mapping the conceptual space and (2) the valuation of the results, which can be translated into practical operational parameters.\u0000 The engineering microservices to derive engineering intelligence include the following: Torsional and lateral instabilities ROP coupled bit wear Hole cleaning Casing wear BHA Drill ahead Mechanical specific energy Hydro mechanical specific energy Motor stall weight (if motor present)","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"24 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":"133730730","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Innovative Machine Learning Method for Predicting Well Performance in Unconventional Reservoirs with a Relatively Small Data Set","authors":"Hui-Hai Liu, J. Zhang, C. Temizel, Moemen Abdelrahman","doi":"10.2118/213288-ms","DOIUrl":"https://doi.org/10.2118/213288-ms","url":null,"abstract":"\u0000 The machine learning method, now widely used for predicting well performance from unconventional reservoirs in the industry, generally needs large data sets for model development and training. The large data sets, however, are not always available, especially for newly developed unconventional plays. The objective of this work is to develop an innovative machine learning method for predicting well performance in unconventional reservoirs with a relatively small data set.\u0000 For a small training data set, the corresponding machine learning model can significantly suffer from so-called overfitting meaning that the model can match the training data but has poor predictivity. To overcome this, our new method averages predictions from multiple models that are developed with the same model input, but different initial guesses of model parameters that are unknowns in a machine learning algorithm and determined in the model training. The averaged results are used for the final model prediction. Unlike traditional ensemble learning methods, each prediction in the new method uses all the input data rather than its subset. We mathematically prove that the averaged prediction provides less model uncertainty and under certain conditions the optimum prediction. It is also demonstrated that the method practically minimizes the overfitting and gives relatively unique prediction. The usefulness of the method is further confirmed by its successful application to the data set collected from less than 100 wells in an unconventional reservoir. Sensitivity results with the trained machine learning model show that the model results are consistent with the domain knowledge regarding the production from the reservoir.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"22 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":"115977699","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":"Optimization Model of Fracture Parameters of Shale Gas Fracturing Horizontal Well Based on Genetic Algorithm","authors":"Xurong Zhao, Tian Lan, Zekai Tang, Lingyu Mu, Lianbo Hu, Zhigang Song, Zhiming Chen, Yicheng Zhou","doi":"10.2118/213337-ms","DOIUrl":"https://doi.org/10.2118/213337-ms","url":null,"abstract":"\u0000 Based on a genetic algorithm and field production data, this paper reasonably optimizes the fracture parameters of multistage fractured horizontal wells (MFHWs). First, a mathematical model of MFHWs in shale gas reservoir is proposed under the conditions of variable production and variable pressure. Then, the main factors affecting well production are determined by sensitive analysis. Finally, the production prediction model based on a genetic algorithm (GA) is used to optimize the fracture parameters of the Fuling shale gas reservoir. The results show that in the study area, the number of fractures in typical wells is 10, and the fracture half-length is 90m, and the fracture conductivity is 15.24mD.m. The effective fracture half-length is the main parameter affecting production, so the effective fracture half-length and effective fracture number should be increased reasonably, and the support concentration should be increased properly. What's more, the optimal solution of fracture half-length is 160m, and the optimal solution of fracture number is 8, and the optimal solution of fracture conductivity is 20 mD·m. This paper provides a new idea based a genetic algorithm for optimizing fracture parameters of shale gas wells in the Fuling area.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"8 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":"128395496","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":"3D Printed Rocks - An Emerging Technology for Systematic Petrophysical Studies","authors":"S. Ma, G. Jin, R. Antle, Brian Wieneke","doi":"10.2118/213383-ms","DOIUrl":"https://doi.org/10.2118/213383-ms","url":null,"abstract":"\u0000 3D printing translates digital models into physical objects, which could potentially be used to print proxies of reservoir rocks from their high-resolution images acquired by such as micro-CT tomography. This paper reviews current 3D printing technologies and explores the capabilities of 3D stereolithography (SLA) technique in rock printing in terms of scale, resolution, accuracy, and repeatability, with the eventual objective of studying factors affecting petrophysical models, such as Archie model, by varying petrophysical inputs of Archie parameters m and n, systematically.\u0000 A 3D printer with the resolution of 10 μm is used to print rock models. Two types of digital models are designed for the 3D printing: Model I contains straight cylindrical pores; 19 pores with diameters from 10 to 100 μm with an increment of 5 μm, and Model II is a virtual core of 1 inch diameter and 2 inch length, created from a computer-generated random uniform sphere pack with a porosity of 30%.\u0000 Model I cylindrical pores of down to 10 μm are printed and clearly observed on their micro-CT images. Pore connectivity is well preserved in the print proxy. However, the printed pore shapes are not completely circular as designed, indicating a challenge of shape preserving in printing. Pore sizes vary along the axis with a standard deviation of approximately 2-3 μm. In Model II virtual core printing, high printing accuracy and repeatability are achieved, while issues of converting from the digital design model to printer recognized STL model are discovered and being resolved.\u0000 With continuous advancements in high resolution imaging, digitalization, and computing power, 3D printing could become a unique and innovative approach enabling manufacturing multiple rock samples for repeatable experiments with identical samples, experiments with systematic variables of such as pore structure or wettability. Challenges faced for printing full-scale pore-structure driven samples can leverage future development and applications of the evolving 3D printing technology.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"32 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":"129132698","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":"Water Injection Optimization Using Geomechanics and PWRI Fracture Modeling, South of Sultanate of Oman","authors":"Salim Al-Busaidi, Ruqaiya Al Zadjali, R. Yuan, Hamid Ghafram, Mohammed Al Amri","doi":"10.2118/213708-ms","DOIUrl":"https://doi.org/10.2118/213708-ms","url":null,"abstract":"\u0000 In the quest to increase production in parallel with reservoir pressure maintenance and to reach the ultimate recovery factor, PDO has been developing the fluvial stacked sandstones using water injection concept under matrix condition. The reservoir is good quality sandstone formation with average porosity (14-24 %) and permeability (20-500mD). The reservoir has weak aquifer support and develops with peripheral water injection. The target VRR is 1 was maintained fairly well in the area in the past few years, until Aug 2020 when few water injectors faced injectivity issues mostly related to the formation itself rather than water quality, so there is a need to compensate for the low cumulative voidage replacement ratio (VRR). Previous study done in year 2015 recommended matrix injection in peripheral mode with possibility to go for controlled fracture injection mode with the need to understand the timeline for fracture propagation to reach the producer wells.\u0000 Geomechanical modeling results were integrated with well and reservoir management (WRM) activities and surveillance technologies to optimize the injection strategy for improved waterflood performance. Formation fracture pressure data were used to provide guidance on maximum allowable injection pressure in injectors to manage the risk of induced fracture growth. A Produced Water Re-Injection (PWRI-FRAC) fracture modeling and analysis was performed to determine the potential fracture dimensions to provide input to development decisions of injection rate and water quality.\u0000 Field data utilized to generate different scenarios of PWRI-FRAC fracture model containment and uncontainment in which the contained fracture scenario indicates that injection higher rates >400 m3/day and TSS=140 ppm, would result in fracture half-length exceeding 1/3 of PI distance towards the end of field life. For small thickness units, models show low risk of fracture growth for rates 100 and 200 m3/Day and TSS=18 and 80 ppm. The rate of fracture growth is primarily influenced by water quality and injection rate. Mapped well spacing for critical wells are around 800-1000m away with orientation towards NE-SW direction, fracture growth modeling results give indication that water injectors are less likely to interact or result in short circuiting with producers if injection with a rate is less than 400 m3/Day and less than 140 ppm of TSS and this is also in line with SH max direction (NE-SW) as seen from drilling induced fractures interpretation from borehole images.\u0000 Fracture injection is feasible as long as the injection rate and water quality are operated under recommended limits (rates <400 m3/Day and TSS< 140 PPM) and this will significantly impact the field waterflood performance. Results provided inputs to reservoir simulations and injection rate envelope. The study benefits the field to minimize risk of injector producer short-circuiting for improved waterflood management.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"39 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":"130202107","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 of Scale Inhibitors for Downhole Capillary Injection Under Ultra High Temperature","authors":"D. Shen, J. Stewart, Kung-Po Chao, S. Cook","doi":"10.2118/213615-ms","DOIUrl":"https://doi.org/10.2118/213615-ms","url":null,"abstract":"\u0000 Scale inhibitors have been widely used in oil and gas production as well as oil processing plants to control the formation of mineral scales. However, most scale inhibitors tend to lose efficiency as scaling temperatures above 400°F due to the thermal degradation of the chemicals. A customer in the Middle East reviewed their scale management strategy for a steam flood project with application temperatures up to 450°F and requested a suitable scale inhibitor for downhole capillary injection to prevent the formation of calcium carbonate and calcium sulphate scales.\u0000 Several scale inhibitor products were selected for scaling inhibition tests based upon known high temperature stability. Dynamic tube-blocking test results indicated that three selective inhibitor products were able to mitigate the formation of calcium scales at 450°F effectively. These three products are fully compatible with the formation waters up to 10,000 ppm and were selected for further thermal stability and corrosion tests. Product A and B had good general corrosivity results, but product B was considered to fail the capillary approval test as there was extensive solid generation/phase separation observed after the thermal aging process at 450°F. Product C was also considered unsuitable as it showed aggressive corrosion rates.\u0000 In conclusion, Product A is recommended for downhole capillary application in this steam flood project based upon the test results in this study and its previous successful downhole capillary application in the field at 400°F. Due to the high application temperature, special precautions may be necessary for preservation of the capillary string.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"20 9","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121003008","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":"Modeling Two-Phase Intermittent/Annular Flow Pattern Transition in High Liquid Viscosity Upward Vertical Wells","authors":"E. Al-Safran, Mohammad Ghasemi","doi":"10.2118/213612-ms","DOIUrl":"https://doi.org/10.2118/213612-ms","url":null,"abstract":"\u0000 Two-phase flow pattern prediction is required for accurate prediction of liquid holdup and pressure gradient in upward vertical wells. Recent studies of flow pattern models evaluation in high liquid viscosity two-phase in vertical pipe upward flow revealed (Al-Safran et al., 2020) discrepancies in all transition boundaries, including the intermittent (IN)/annular (AN) transition. This study aims to investigate the effect of liquid viscosity to improve Taitel et al. (1980) and Barnea (1987) IN/AN flow pattern transition models predictions. Taitel et al. liquid droplet fallback model is modified by incorporating liquid viscosity effect in the critical Weber number to predict droplet terminal velocity. In addition, this work eliminates the assumption of negligible annular film thickness (due to high viscosity liquid) in predicting the critical gas velocity to transport liquid drop upward, i.e. transition to intermittent flow. Sensitivity analysis revealed that the interfacial friction factor (fi) and liquid entrainment (fE) closure relationships are crucial in Barnea (1987) film bridging and film instability IN/AN transition models. Therefore, a comprehensive evaluation of fi and fE correlations and their combinations revealed that the combination of Pan and Hanratty (2002) fE correlation and Ishii and Grolmes (1975) fi correlation is the best, i.e. produces least prediction error, for wide range of liquid viscosity. A validation study against large experimental database of high liquid viscosity (4 mPa.s to 1600 mPa.s) flow pattern showed high prediction efficiency for the improved Taitel et al. and Barnea IN/AN transition models.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"31 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":"116637784","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 Online Natural Gas Composition Analysis by Low-Field NMR Spectroscopy","authors":"O. Mohnke, H. Thern, Sergio Ortiz, A. Świątek, Andreas Ohligschläger, Anton Duchowny, Pablo M. Dupuy, H. Widerøe, Øyvind Leknes, M. Küppers, A. Adams","doi":"10.2118/213537-ms","DOIUrl":"https://doi.org/10.2118/213537-ms","url":null,"abstract":"\u0000 The most common NMR methods in the oil and gas industry are NMR relaxometry and diffusometry. Relaxation times T1 and T2 as well as diffusivity D are determined for characterizing fluids and their surrounding pores in logging applications or laboratory analyses. NMR spectroscopy is rarely used for petrophysical investigations but primarily in medical, food, and material applications. In a joint operator-academia-service company project, we explore opportunities for gas component quantification by low-field NMR spectroscopy with the prospect of rig-site, production-plant, and sea-floor deployment. Using an affordable benchtop device in a production-like environment, we gained a fundamental understanding for a commercially viable application of low-field NMR spectroscopy and translated this knowledge into a practical workflow for online natural gas composition analysis.\u0000 We measured typical natural gas components (all isomers from methane to n-hexane) with a portable desktop NMR spectrometer working at a proton resonance frequency of 60 MHz A hardware setup was manufactured for mimicking a gas production environment up to 200 bar. A database was populated by NMR signatures of pure gas components, derived from measurements on pure components and binary mixtures. Additional efforts were dedicated to understanding and quantifying systematic effects on the hydrocarbon NMR spectra connected to sample composition and pressure. Pre- and post-processing data procedures were developed and applied for substantially increasing robustness of the method and further improving the gas composition analyses results. Using an indirect hard modeling (IHM) analysis, the constituting pure components in binary, ternary, and more complex gas mixtures were identified and quantified. IHM automatically accounts for small variations and uncertainties in the NMR spectra. The results from the NMR spectrum analysis are in very good agreement with vendor certificates of gas composition obtained from gravimetrics and gas chromatography.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"44 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":"125248669","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":"Down Hole Data Driven Optimization on Bit, Parameters and BHA Lead to an Outstanding Performance in Deep Gas Drilling","authors":"R. Kouzaiha, Chris Cleboski, Kyle Vrnak, D. Daechsel, Nadir Al Rawahi","doi":"10.2118/213645-ms","DOIUrl":"https://doi.org/10.2118/213645-ms","url":null,"abstract":"\u0000 Deep gas drilling the early Devonian unconformity in Oman is an extremely challenging hard and abrasive application fraught with a diverse set of PDC drill bit challenges and objectives, particularly in the 8 3/8″ vertical section where between 2 to 4 fixed cutter drill bits can be necessary to reach total depth. Each trip can significantly impact well construction cost and delay production on stream dates. Using high frequency digital data collected at the drill bit and detailed forensic analysis of drill bit photographs a new, physics based, drilling equipment and parameter strategy was developed.\u0000 The section requires drilling approximately 2,000m of hard and abrasive interbedded Sandstone and Shale formations to around 5,000m vertical depth. Drilling performance is typically limited by severe wear to the PDC cutting structure or motor failure from significant torsional and lateral vibrations. High frequency digital data was captured at the bit in conjunction with output data from an automated photometric dull grading system over several wells to identify dysfunction type. The results were then analyzed by vendor and operator SMEs collaboratively to optimize drilling parameter performance and provide insights into optimal cutter shape and grade selection to further reduce drilling dysfunction.\u0000 Using downhole high frequency digital readings to understand down hole vibrations and the impact of formation interaction on bit dull has led to changes in the cutting structure and the applied drilling strategy. Different drilling approaches were applied to each formation layer to manage interbedded transitions as well as to increase depth of cut for improved drill bit dynamic stability. Insights were derived from an automated dull grading system assisted in optimizing cutter shape and grade selection in the select parts of the drill bit cutting structure. The photometric analysis also helped refine drilling parameters for a more efficient drilling by increasing axial loading on hard formations that then resulted in increased ROP. Additionally, newly developed high abrasion resistant cutters placed optimally in the drill bit at the highest work locations based on automated dull grading feedback resulted in extended cutter life helping to keep the bit sharp and maintain the high rate of penetration through the various layers reaching final section depth with consistently high rate of penetration.\u0000 The execution of the new physics-based drilling strategy has resulted in improved bit dull grade conditions which helped reaching the section final depth in one run with reduced downhole dysfunctions. that resulted in a section drilled without trips and with reduced well construction costs. The section is 32% faster than the offsets and was drilled 7 days earlier compared to plan.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"1 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":"127635642","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}