Day 2 Mon, February 20, 2023最新文献

{"title":"UAEs Unconventional High-Pressure/High-Temperature (HPHT) Shale Gas Play Appraisal Technical and Operational Learnings","authors":"Azeizah Al hassani, Pierre Van Laer, Trevor Brooks, Muhammad Z. Baig, Serif Elazab, D. Caillon, Yang Wu, Leandro Kolton","doi":"10.2118/213282-ms","DOIUrl":"https://doi.org/10.2118/213282-ms","url":null,"abstract":"\u0000 The paper outlines the technical and operational journey experienced in completing this appraisal program, from wellbore preparation to the production. The paper will describe how the intervention tools and practices varied between the two wells drilled in same target and 500 ft a part. Also, the paper going to address the maximize operational efficiency, reduce emissions and availability of local resources. In addition to the modification and customization of available technologies and tools to address the UAE unconventional formations.\u0000 Multistage well completions have been developed in the last two decades. Much of this advancement can be attributed to the unconventional shale Oil and Gas plays technology revolution, in which numerous transformational tools, techniques, and concepts have led to the efficient development of ultralow- permeability resources on a massive scale. However, careful consideration must be taken because these techniques cannot be used in areas outside in early in life fields, where reservoir rock properties and stress regimes are considerably different. Therefore, if not properly designed this can compromise the effectiveness of the hydraulic fracture treatment and impair project success which, impact energy self- sufficiency followed by strategy for the country. Diyab Reservoir is an organic-rich limestone unconventional play and our focusing area is located in Al Dhafra region, 250 km west of Abu Dhabi. The target formations comprise of extremely high stress rock in addition to the high-pressure and high temperature (HPHT).\u0000 The appraisal strategy included two horizontal wells PAD that completed simultaneously (zipper) with massive multistage hydraulic fracture treatments using the perf and plug technique. Wells were long term flow tested through an early production facility to reduce emission while collecting key information to reduce the associated uncertainties and design a robust field development plan.\u0000 The obstacles that have been faced and are still ongoing with this campaign is highlighting the importance of several critical factors. These including multidisciplinary integration and planning, wellbore construction impacts, contractor performance and tool reliability. This paper is providing a summary of case histories and operational results for the first horizontal wells intervention techniques used in UAE high-pressure and high-temperature (HPHT) reservoirs. This represents a very important contribution and key factors to UAE Gas self-sufficiency and Energy transition strategy plan.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"96 S2","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113960714","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":"Superactive Surfactant for Enhanced Oil Recovery","authors":"Azizah AlRadhwan, Mohammed Al Hamad, Wael Abdallah","doi":"10.2118/213480-ms","DOIUrl":"https://doi.org/10.2118/213480-ms","url":null,"abstract":"\u0000 After primary and secondary oil recovery, a large amount of oil is left behind in the reservoir. Enhanced oil recovery (EOR) techniques are introduced to recover additional oil from the reservoir. Chemical EOR is one of the commonly used EOR techniques. It involves the use of chemical substances such as surfactants. Surfactants are commonly used in the petroleum industry because they have the ability to change the water-oil interface as well as the properties of the rock surface. The use of such surfactants depends on technical, financial, and environmental factors. In this study, the performance of a new superactive surfactant is evaluated for use as an oil recovery agent for carbonate and sandstone formations. The surfactant showed high stability in deionized water and seawater, with strong ability to lower the interfacial tension of different crude oils (light, medium, and heavy) at a very low concentration (i.e., 0.05 wt%). The maximum reduction in interfacial tension reached 99.5%. The surfactant also showed significant surface wettability alteration toward water-wet at the tested concentration, with maximum reduction of 87%. From the interfacial tension and wettability experiment results, the optimum system was obtained for the medium crude oil and seawater at surfactant concentration of 0.05 wt%. Therefore, the coreflooding experiments on carbonate and sandstone samples were carried out using this system. Results showed a significant additional oil recovery by the surfactant injection. Additional oil of 43% was recovered from the carbonate core samples, while 16% recovered from the sandstone sample. With these results, this new surfactant can be potentially considered as a new agent for enhancing oil recovery from carbonate and sandstone formations.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"177 5","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-07","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114037659","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":"Scale-Up Fabrication and Microfluidic Evaluation of Janus Graphene Nanofluids as Novel EOR Agent","authors":"Wei Wang, Sehoon Chang, Gawain Thomas","doi":"10.2118/213484-ms","DOIUrl":"https://doi.org/10.2118/213484-ms","url":null,"abstract":"\u0000 Nanofluid flooding is an emerging enhanced oil recovery (EOR) technique whereby injection fluids containing nanoparticles or nanocomposites are utilized for the oil displacement or injectivity improvement in oil reservoirs. However, current nanofluids with conventional nanoparticles have relatively low efficiency for EOR at simulated reservoir conditions, especially at low concentrations of nanoparticles. This research reported a new cost-effective method for scale-up synthesis of Janus graphene nanosheets and demonstrated a new type of nanomaterials, Janus nanofluids, as highly effective alternative nano-agents for EOR applications. A lyotropic liquid crystal phase as a novel \"interfacial nano-reactor\" system has been developed for fabricating Janus nanomaterials at nano-scaled liquid-liquid interfaces. Compared to interfacial reaction in a conventional bi-phase system, the new \"interfacial nano-reactors\" could tremendously enlarge the interfacial area by more than million times for chemical reactions at the interface, and thus allow production of Janus nanomaterials in mass quantity economically for industrial applications. Janus graphene nanosheets synthesized via this method have been characterized and confirmed by multiple techniques including scanning electron microscopy (SEM), Langmuir-Blodgett (LB) isotherm, contact angle, and interfacial tension (IFT) measurements. Interfacial tension measurements have shown that the Janus graphene nanosheets could significantly lower the IFTs between brine and crude oil at simulated reservoir conditions. With low concentration of Janus graphene nanosheets in nanofluid formula, microfluidic flooding experiments have been performed to evaluate the efficiency of the nanofluids for oil displacement in carbonate reservoirs. The results have demonstrated improved efficiency of oil recovery by the novel Janus graphene nanofluids at ultra-low concentration (0.01 wt%).","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"133 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":"114522037","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":"Environmentally Friendly Nanoshale Inhibitor Water-Based Drilling Fluids","authors":"H. S. Alqahtani, Mohammed K. Arfaj, M. Alhassni, M. A. Alotaibi","doi":"10.2118/213755-ms","DOIUrl":"https://doi.org/10.2118/213755-ms","url":null,"abstract":"\u0000 Metal Oxide Nanoparticles (MONPs) comparison has been used for the first time as Nanoshale inhibitors in water-Based Drilling Fluids. These Nanoshale inhibitors used in this study eliminate the use of toxic high potassium chloride (KCl) concentration in shale drilling operations and environmentally friendly with reducing the cost of drilling fluid treatment and waste disposal.\u0000 The dispersion test of Nanoshale inhibitors based on MONPs with shale samples revealed to be an effective candidate with significant interaction reduction between the drilling fluids and the shale particles compared without these Nanoshale inhibitors samples. This new Nanoshale inhibitor maintains the integrity of the cuttings and minimize the interaction of fluids with shale sections during the rolling test. Zeta potential (ZP) has been conducted to determine the charge of shale and nanoparticles samples.\u0000 Although the application of nanoparticles to improve the performance of conventional water-based drilling fluid was studied by researchers, it is the novelty of this research to eliminate use of KCl and to develop the new generation of Nanoshale water-based drilling fluid with economical consideration and lower environmental impact.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"28 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":"114400766","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":"Advanced Hole Cleaning in Horizontal Wells: Experimental Investigation Supported by a Downhole Clamp-On Tool","authors":"Jelena Skenderija, Alexis Koulidis, Domingo Lattanzi Sanchez, Shehab Ahmed","doi":"10.2118/213675-ms","DOIUrl":"https://doi.org/10.2118/213675-ms","url":null,"abstract":"\u0000 Up to 80% of stuck pipe events are hole cleaning related in the case of high-angle wells. Therefore, significant attention should be given to understanding hole cleaning as it is crucial to restricting stuck pipe-related non-productive time (NPT). In order to optimize hole cleaning efficiency, the fundamental objective of the proposed paper is to experimentally investigate cuttings transport supported by a downhole clamp-on tool.\u0000 This work approaches existing challenges by designing and building a custom flow loop that recreates the drilling environment of horizontal wells. The study provides additional steps and new ideas in developing a reliable experimental setup for a proper hole cleaning investigation. Accordingly, the process includes comprehensive dimensional analysis, detailed design, and building a desired experimental flow loop setup. A unique mechanical design allows pipe rotation while achieving a closed-loop system. A clamp-on tool assists in agitating the cuttings to reduce accumulation at the bottom of the borehole. Experimental performance with various cuttings compares scenarios with and without pipe rotation.\u0000 Among the key factors influencing cuttings transport in horizontal wells are drill pipe rotation (RPM), flow rate (Q), mud rheology, cuttings size, flow regime, and penetration rate (ROP). This research focuses on the mechanical removal of solid cuttings. Experimental work emphasizes cuttings' behavior showing different patterns for their movement in deviated wells by utilizing image processing. Drillstring rotation proves to be a crucial factor for efficient hole cleaning. The specific shape and dimensions of the clamp- on tool affect the efficiency of the hole cleaning process and impact the distance covered by the agitated cuttings downstream of the tool. The concept of the tool depends on blades that agitate cuttings as it rotates. Optimum tool design considers the physical properties of the fluid and the cuttings. The results show that as the tool agitates cuttings and moves them into the higher velocity region, the cuttings advance with the flow, which improves cuttings transport and reduces bedding formation. Assuming low flow rates, tool application increased average particle velocity within the tool more than four times (372%) and twice after the tool. In addition, differential pressure (Δp) shows a significant decrease while the tool operates, indicating improvement in hole cleaning.\u0000 Lab-scaled flow loop development aims to simulate drilling conditions with drillpipe rotation and different downhole clamp-on tool geometries. The results show different flow patterns from experimental observations of liquid-particles flow in the horizontal wellbore, assisted by the proposed downhole clamp- on tool. The innovative tool design is a promising step in reducing hole cleaning issues with mechanical- assisted tools.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"97 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":"124182393","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":"Selection and Optimization of Demulsifier Based on Physio-Chemical Characteristics of Emulsion","authors":"Ali R. Altowilib, R. Gajbhiye, M. Mahmoud, T. Sølling","doi":"10.2118/213617-ms","DOIUrl":"https://doi.org/10.2118/213617-ms","url":null,"abstract":"\u0000 The presence of crude oil/water emulsions is a burden in the petroleum industry. It leads to several operational and economic issues related to crude production, transportation, and refining processes. The stability of the emulsified oil is affected by water content, presence of organic/inorganic materials, formation brine salinity, and temperature. In reservoir fluid studies, applying chemical demulsifiers on emulsion samples is common to break the emulsion and reduce the water content to an acceptable level (less than 1 wt. %) to generate representative fluid composition results. However, this process depends heavily on the crude and the water compositions and the type of demulsifier used. An incompatible choice of demulsifier could strengthen the emulsion's stability or alter the fluid composition. This introduces the need to understand specific physiochemical properties to identify the root causes of demulsifier ineffectiveness.\u0000 In this study, two demulsifiers containing different functional groups (Type 1 and Type 2) were evaluated for their emulsion breakage ability. Nine oil samples from various fields were mixed with formation water in the first round and seawater in the second. The water-oil ratio of 80:20 was achieved using a blender for 1.5 minutes at 300 RPM. Saturates, Aromatics, Resins, and Asphaltene (SARA), viscosity, density, and sulfur content were determined for all oil samples. Furthermore, chemical analysis was conducted on all water samples to determine Total Dissolved Solids (TDS). After applying both demulsifiers at the same concentration (1% of total volume), separated water volumes were measured at 5, 10, 15, and 20 minutes and used to calculate the emulsion separation index (ESI). Results of this work showed that Type 1 demulsifier performed better than Type 2 in the formation water and seawater and while using different oils due to the resistance of the non-ionic surfactant to salinity, polarity, and water hardness. This study shows a methodology for effectively determining the optimum chemical demulsifier type to break emulsions by adequately understanding the chemistry of the oil, brine, resulting emulsions, and demulsifiers used.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"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":"122107266","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 Wellbore Safety: Closed-Loop Limit Control of Tripping Operations","authors":"Pedro J. Arévalo, G. Becker, R. May, Alaa Alalawi, M. Forshaw, S. Grymalyuk, Yazeed Qahtani","doi":"10.2118/213363-ms","DOIUrl":"https://doi.org/10.2118/213363-ms","url":null,"abstract":"\u0000 A significant part of well construction is invested in tripping drill pipe. This type of operation is considered not productive in terms of drilled wellbore but is however necessary for the well construction process. The associated cost of tripping operations can be as high as 30% of the overall well CAPEX and poses an attractive optimization case to reduce spending by means of increasing efficiency. Furthermore, a byproduct of increased efficiency is a cleaner operation in terms of carbon emissions.\u0000 Increasing efficiency for tripping operations concerns two main components: reducing connection time and optimizing the motion of the string while tripping in and out of the wellbore. The connection time can be reduced by means of machine automation to deliver repetable and safer handling of the drill pipe during connections. Optimizing the tripping parameters to move the string requires a more complex approach, where physics-based modeling plays a key role in determining a safe operating envelope (SOE) to move the string without harming the formation or the surface equipment in the process. The system described in this paper touches upon this problem and includes the concept of interfacing to automated drilling control systems (ADCS) to achieve closed-loop control of tripping operations.\u0000 The solution proposed deploys a hydraulic digital twin of the wellbore that estimates the permissible axial velocities and accelerations to use when running drillstring in and out the wellbore. The same digital twin is used during pre-job modeling to verify proposed tripping plans, and later on in real-time to update the tripping limits for velocity and acceleration for every stand as the tripping process continues. The results produced in real-time are published to a data aggregation layer to serve as input for a tripping automation application to refine fit-for-purpose monitoring and control algorithms. The automation system finds optimum proposals of tripping limits and updates them directly in the rig control system in real-time.\u0000 The trip monitoring system automatically and continuously publishes optimum velocity and acceleration tripping limits per stand and transmits them as set points to the ADCS to define a safe operating envelope (SOE). This approach can greatly reduce the overall tripping time in comparison to non-automated deployments. Furthermore, the reduction of invisible lost time (ILT) takes place while maintaining the integrity of the formation, and the integrity of the surface equipment.\u0000 A set of case studies confirm the effectiveness of the approach and illustrate its benefits. A case study from the Middle East addresses the topic of adoption of drilling automation applications such as the tripping advisor. Another case presents the concept of interoperability using as example a deployment on a rig simulator setup in Europe to perform closed-loop control using the tripping application to write velocity and acceleration limits continuously to","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"381 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":"116637868","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":"Tailored Cement Systems with Enhanced Mechanical Properties Designed to Eliminate Sustained Casing Pressure in Development Wells","authors":"Pushkara Varma Chekuri, A. Singhal, Sheraya Kaura, M. Dange, Animesh Kumar, Swarnima Singh","doi":"10.2118/213655-ms","DOIUrl":"https://doi.org/10.2118/213655-ms","url":null,"abstract":"\u0000 \u0000 \u0000 Oil and gas wells in the Barmer fields (Rajasthan, India) typically require a timeframe of five to seven days for well completion. The cementing process includes a wide range of challenges, including low fracture gradients, lost circulation, and sustained casing pressure (SCP). Because the baseline challenges were identified from cementing through completion phases, the target was to design a tailored, gas-tight, resilient, lightweight cement system to address wellbore integrity issues. The modelled simulations showed the rheological behaviour, equivalent circulating density (ECD), pumping rates, and maximum surface pressure, whereas the 3D model predicted the sweep efficiency of the pumped fluids. Elastomeric materials were incorporated into the designs to counter the stresses induced during well activities. Advanced laboratory testing was performed to ensure that these lightweight slurries met the requirements to address multiple issues by exhibiting suitable mechanical properties (based on finite element analysis (FEA) simulation output), gas-tight behaviour, and lost circulation curing capabilities. Three stable cement slurries were designed with the available set of additives to simplify operations.\u0000 Elastomeric additives altered the mechanical properties of the set-cement sheath to provide greater resilience than conventional cement. More than 22 wells were cemented with a varied range of densities that were designed/modified with the available chemical additives, based on the severity of the depleted reservoir zones. To ensure completion of the full process (ranging from design to completion of the cement job), multiple verifications/checks were implemented. Quality control played an important part, and all new bulk blended batches were tested for mechanical properties. The wide range of densities and sensitivity tests of the cement system assured reliable implementation.\u0000 The successful design and cemented completion resulted in the reduction/elimination of sustained casing pressure. SCP, which may have been a safety hazard, influences production rates and, in the worst case, could compromise the structural integrity of the well. Results indicated that more than 90% success was achieved in the targeted segment of the field, in terms of SCP in the B-annulus (after cementing and perforation of the wells) where the values were well below their maximum allowable limits. The returns to surface, excellent cement bond logs, microseismogram, circumferential visualization, and zonal isolation under lost circulation conditions further justified the performance of enhanced slurry designs.\u0000","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"362 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":"115783077","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 Simulator for Minimizing Openhole Breakdown Pressure through Notch Shape Optimization","authors":"Yanhui Han, M. AlTammar, K. Alruwaili","doi":"10.2118/213310-ms","DOIUrl":"https://doi.org/10.2118/213310-ms","url":null,"abstract":"\u0000 Wellbore breakdown pressure is an important parameter utilized in hydraulic fracturing stimulation design. Because of the stress concentration around wellbore and formation strength, the borehole breakdown pressure is often much higher than the minimum confining stress plus tensile strength. To overcome the barrier of the stress concentration and locate the fracture initiation spot, well is often perforated or notched before the hydraulic fracturing treatment. Qualitatively, it is well observed and accepted that perforations and notches can reduce the breakdown pressure; quantitatively, however, there is a demand for reliable and accurate method to predict how much various perforating or notching configurations can help reduce the breakdown pressure. In this paper, a computational mechanics simulator is developed to predict the breakdown pressure inside a notched wellbore subjected to loading of in-situ stresses. The simulator can predict the breakdown pressure for a well with a given notch stimulated with fluid injection. It can also be used to optimize the design of a notching tool which can minimize the breakdown pressure during hydraulic fracturing. The simulator is applicable to cases of both longitudinal and transverse notches.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"68 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":"126330063","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":"Utilizing Drilling Data and Machine Learning in Real-Time Prediction of Poisson's Ratio","authors":"Osama Mutrif Siddig, S. Elkatatny","doi":"10.2118/213694-ms","DOIUrl":"https://doi.org/10.2118/213694-ms","url":null,"abstract":"\u0000 Rock elastic properties influence drilling performance, estimation of in-situ stresses, and hydraulic fracturing design. Therefore, having complete and accurate information on rock properties is essential. While those properties are conventionally measured experimentally or using well logs, this work proposes to estimate the Poisson's ratio (PR) from parameters available while drilling.\u0000 Various machine learning techniques were employed, such as artificial neural network (ANN), support vector machine (SVM), and random forest (RF). The dataset utilized contains more than 5800 data points, each of them has a value of PR and six drilling parameters such as rate of penetration (ROP), rotary speed (RPM), and weight on bit (WOB). The dataset was divided into three parts, two were fed to the algorithms for training and testing the models, while the last group (around half of the dataset) was hidden to be used to validate the models later.\u0000 The models had a good fit with the actual PR values with correlation coefficients as high as 0.99 and errors as low as 1%. Among the used algorithms, ANN and RF yielded the best accuracy in all datasets with no significant difference between the training and the validation performance which indicate good generalization without an overfitting problem.\u0000 Using drilling data to predict rock mechanical parameters allows building a complete geomechanical model at an early time. It also saves the time and cost associated with laboratory tests.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"76 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":"126126576","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}