Day 2 Mon, February 20, 2023最新文献

{"title":"Rigless Repair of Packer Leak Via Annular Cement Plug","authors":"A. Yugay, Majed Ahmed Majed Ahmed Alkarbi, Yunus Berdiyev, Indra Utama, Mohammed Thani Al Hamadi, Karam Hassan, Afnan Al Marzooqui, Hajer Alshehhi, Gabriel Rincon, Shamsa Al Menhali, Taha Ramadan, Mohammed Sayed Al Baloushi, Sheriff Hassan Elhanbouley, E. Metlyaev, Indra Respati, Rabie Eliatar, Enggal Setioko","doi":"10.2118/213733-ms","DOIUrl":"https://doi.org/10.2118/213733-ms","url":null,"abstract":"\u0000 Well double barrier envelope policy is a common industry practice and main philosophy of well integrity discipline. It is well-explained in well integrity related international standards: API RP90 (1 & 2), Norsok D10, ISO 16530 (1 & 2).\u0000 It states that all wells with positive pressure at surface capable to flow naturally should have primary and secondary barrier envelope. Primary barrier envelope consists of well equipment which is continuously in direct contact with hydrocarbon and is pressurized. In case primary barrier failure (leak through the tubing, packer, or other completion equipment element), secondary barrier envelope is the one that holds the pressure and prevents further escalation of the incident outside of well boundaries. The content of this paper is related to such kind of wells that comply to the double barrier policy and are equipped with production packers.\u0000 Conventional process of curing packer leak is to re-complete the well during rig intervention – the workover. During this process old completion is retrieved and new completion is installed. This operation can be repeated multiple times. Failure of any element of the primary barrier envelope results in the sustainable pressure in annulus \"A\" – SAP pressure. Such SAP wells is a violation from double well barrier policy and create a hazardous situation.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"9 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":"134053093","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":"Research of Polymeric Surfactant as Multifunctional Monocomponent Oil Displacement Agent in EOR","authors":"Zhiqing Su, Hui Xu, Yingcheng Li, Hui-Ping Sun, J. Jin, Bin Wang, Aiqing Ma, Xiujuan He, O. Sha","doi":"10.2118/213456-ms","DOIUrl":"https://doi.org/10.2118/213456-ms","url":null,"abstract":"\u0000 SP (Surfactant-Polymer) flooding is one of the most common methods in Enhance Oil Recovery (EOR). However, chromatographic separation underground limits its efficiency due to the enormous difference in molecular size between polymer and surfactant.\u0000 A single-component oil displacement agent, polymeric surfactant (PolyS), was studied to solve the chromatographic separation. Properties were investigated under the reservoir conditions, including viscosity, interfacial activity, injectivity, adsorption, and core flooding.\u0000 With the increase of the active functional group content, the viscosity decreased, while the oil-water interfacial activity increased. The viscosity of PolyS was higher than 10mPa∙s, and interfacial tension (IFT) was lower than 3×10-2 mN/m at 2500 mg/L PolyS in the brine with a salinity of 66560 mg/L at 72°C. The middle phase emulsion was formed when mixing crude oil and PolyS solution, indicating that PolyS had better capability to emulsify crude oil than commercial polyacrylamide (PAM). Furthermore, the adsorption amount of PolyS on silica with diameter of 100-150 μm was 1.16 mg/m2.\u0000 PolyS can be easily injected into sandpack with different permeabilities from 300 mD to 1000 mD. The oil displacement results showed that an improved oil recovery of 26.15% OOIP was achieved with an injection of 0.3 PV PolyS solution containing a 2.04 mol% active functional group, which had both low IFT and high viscosity. As a comparison, only 20% OOIP was obtained for commercial PAM.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"25 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":"117125393","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 a Deterministic Total Organic Carbon (TOC) Predictor For Shale Reservoirs","authors":"Mohammad Rasheed Khan, S. Kalam, Abdul Asad, Sidqi A. Abu-khamsin","doi":"10.2118/213350-ms","DOIUrl":"https://doi.org/10.2118/213350-ms","url":null,"abstract":"\u0000 Unconventional reservoirs like shale oil/gas are expected to play a major role in many unexplored regions, globally. Shale resource evaluation involves the estimation of Total Organic Carbon (TOC) which correlates to the prospective capability of generating and containing hydrocarbons. Direct measurement of TOC through geochemical analysis is often not feasible, and hence researchers have focused on indirect methods to estimate TOC using analytical and statistical techniques. Accordingly, this work proposes the application of artificial intelligence (AI) techniques to leverage routinely available well logs for the prediction of TOC. Multiple algorithms are developed and compared to rank the most optimum solution based on efficiency analysis.\u0000 Support Vector Regression (SVR), Random Forest (RF), and XGBoost algorithms are utilized to analyze the well-log data and develop intelligent models for shale TOC. A process-based approach is followed starting with systematic data analysis, which includes the selection of the most relevant input parameters, data cleaning, filtering, and data-dressing, to ensure optimized inputs into the AI models. The data utilized in this work is from major shale basins in Asia and North America. The AI models are then used to develop TOC predictor as a function of fundamental open-hole logs including sonic, gamma-ray, resistivity, and density. Furthermore, to strengthen AI input-output correlation mapping, a k-fold cross-validation methodology integrating with the exhaustive-grid search approach is adopted. This ensures the optimized hyperparameters of the intelligent algorithms developed in this work are selected. Finally, developed models are compared to geochemically derived TOC using a comprehensive error analysis schema.\u0000 The proposed models are teted for veracity by applying them on blind dataset. An error metrics schema composed of root-mean-squared-error, and coefficient of determination, is developed. This analysis ranks the respective AI models based on the highest performance efficiency and lowest prediction error. Consequently, it is concluded that the XGBoost and SVR-based TOC predictions are inaccurate yielding high deviations from the actual measured values in predictive mode. On the other hand, Random Forest TOC predictor optimized using k-fold validation produces high R2 values of more than 0.85 and reasonably low errors when compared to true values. The RF method overpowers other models by mapping complex non-linear interactions between TOC and various well logs.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"18 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":"117183983","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":"Setting ESP Packer at High Inclination Intervals Using a Creative Completion Design Achieving 30% Completion Time Savings in a Middle East Oil Field","authors":"Mustafa Almuallim, R. Agarwal, Paul Silva, Jaffar Al Shaikh, Mohammad Al-Herz","doi":"10.2118/213683-ms","DOIUrl":"https://doi.org/10.2118/213683-ms","url":null,"abstract":"\u0000 After years of oil production, conventional ESP placement at shallow depth ~ inclination of 45° is no longer capable for production and thus the need to push the ESP deeper and closer to the reservoir at 55°-85° deviation is deemed necessary, which negatively impacts the ability to set packers using conventional slickline systems. A novel approach of setting ESP packers is presented in this paper, featuring a modified completion design that allows the packer to be set at any inclination without the use of conventional methods like coil tubing, wirelines, or slick lines.\u0000 To begin with, the paper provides an overview of technologies that are currently being used to overcome the challenges associated with setting production packers at an incline exceeding 45°. It introduces an alternative approach to set packer using a simple, yet an innovative modification in the design of completion assembly despite historical challenges associated with packer placement at highly deviated intervals. The Optimized system creatively integrates application of multiple fit to purpose technologies and valves assembly across the completion string. This assembly can be operated to allow string self-filling and holding pressure from above which provides a simple method of hydraulically setting ESP packer. Additionally, other technologies were used to ensure hydraulic cables and lines are safe and away from any potential pinch point especially while running through deviated intervals. Finally, study concludes with detailed design criteria and description, execution road map and contingencies.\u0000 This system was successfully implemented across 5 extended reach wells (ERD) with packer planed at an inclination range of 64° to 86°. Revised approaches enabled time reduction of over 30% compared to other wells across which packer was set with conventional, time consuming and risky operation like coiled tubing and wireline tractor. Optimized completion design is currently adopted by operator as standard practice to set ESP packer across highly deviated trajectories for both multi and single lateral extended reach oil producers in a particular field in the middle east.\u0000 The document provides a novel approach to set production packer at high inclination by utilization of optimized and simple completion design compared to expensive and time-consuming alternative approaches. This can easily be duplicated worldwide to optimize production packer setting especially at high inclination and thereby saving tremendous time and cost.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"342 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":"123323880","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":"Asphaltene Testing for Inhibitor Evaluation","authors":"D. Jennings, Abhishek Golchha, Justin Breitigam, A. Yen, Kui Xu","doi":"10.2118/213616-ms","DOIUrl":"https://doi.org/10.2118/213616-ms","url":null,"abstract":"\u0000 Asphaltenes are a global flow assurance problem responsible for reduced production and increased operating costs in many oilfields. Asphaltene inhibitor programs are needed to manage problems and increase operational profitability. Improvements are needed in both developing new inhibitors with better performance and in the understanding and application of testing methods used for evaluating inhibitors.\u0000 This paper discusses ongoing efforts to improve our understanding of asphaltene deposition and inhibitor testing with a goal to be able to correlate testing results to satisfactorily predict asphaltene inhibitor field performance before application. Three different asphaltene test methods used in our laboratory are presented. The methods include both live and dead crude oil testing. Results from testing with each method and their relevance to field conditions are discussed. More focus is given on the dead-oil testing methods though as live-fluid testing, being more difficult and costly, is not an option for many field studies. Fundamental deposition studies are shown from one of these methods, highlighting the effect of varying different test conditions on deposition. Finally, a case history of a successful asphaltene inhibitor field application is included at the end of the paper. It is included to provide an example of the benefits of an effective asphaltene inhibitor application and show some comparisons between laboratory testing and field experience.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"225 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":"122527571","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":"Preparation and Properties Investigation on Sand-Polyacrylamide Composites with Engineered Interfaces for Water Shutoff Applications","authors":"Ayman Almohsin, M. Krishnan, E. Alsharaeh, Bader Harbi","doi":"10.2118/213481-ms","DOIUrl":"https://doi.org/10.2118/213481-ms","url":null,"abstract":"\u0000 Herein, we report a facile preparation and characterization of polyacrylamide (PAM)-2D nanofiller (commercial graphene (CG) and hexagonal boron nitride nanosheets (h-BN)) composite hydrogel coated sand for water shutoff application. To prepare the sample, 4 wt% of aqueous PAM solution that is mixed with organic cross-linkers of hydroquinone (HQ) and hexamethylenetetramine (HMT) in 1:1 weight ratio, aqueous potassium chloride (KCl) solution and a specific amount of CG or h-BN. A specific amount of the above solution is added to sand and well mixed and subsequently cured at 150 °C for 8 hours. The prepared sand-polymer composites were characterized by Fourier-transform infrared spectroscopy (FT-IR) for chemical composition, X-ray diffraction (XRD) for successful polymer coating onto the sand, thermogravimetric analysis (TGA), and differential scanning calorimetry (DSC) for thermal stabilities. the success of the sand coating was evaluated based on the peak intensities depicted for the sand-PAM gels with respect to neat-sand and neat-PAM. The absence of some of the peaks and their corresponding decrease in the intensities indicates the successful coating of the PAM hydrogel matrix onto the sand surface. The thermal stability of the sand samples has reached as high as 190.7 °C. The prepared material has a high potential for water shutoff applications.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"25 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":"129191033","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 Niger Delta Process Safety Dilemma: Restoring & Maintaining Well Integrity in the Face of Perennial Asset Vandalization","authors":"Arthur Bougha, Temitope Alalade, Ugoh Oluwatobi, N. Eze","doi":"10.2118/213278-ms","DOIUrl":"https://doi.org/10.2118/213278-ms","url":null,"abstract":"\u0000 Safely operating Oil and Gas wells in the Niger Delta region of Nigeria has become quite challenging to achieve owing to the prevalent vandalization of assets in the operating environment. The asset vandalization ranges from minor theft of Christmas tree accessories, flowlines vandalization, to major wellhead damages and in some cases, wells get blown up with explosives by criminal elements. The major dilemma for the operations teams in this environment lies around how to (not only) restore integrity on wells with a complex state of vandalism, but also how to produce these wells safely.\u0000 Restoring integrity on vandalized wells depends on nature of damage. For subject wells, the complete wellhead systems were severed and carted away with only Down Hole Safety Valve and production packer preventing the release of hydrocarbon. Restoration included design of a false rotary, fishing of the severed tubing stumps on drill pipes, installation of plugs above the safety valve and chemical cut of the tubing above the plug. Casing plug was installed above cut tubing depth as second barrier.\u0000 Casings were then cold cut below impacted depth and tied back to surface. NDT, heat treatment carried out on weld joints.\u0000 In this paper, the unconventional well integrity challenges faced in the Niger Delta onshore wells (Ukp- wells 1, 2, 3 and 5) and the in-house capabilities (innovative and unconventional steps) developed to address these challenges are presented. The wells in this paper had all concentric tubulars severed from below the casing head housing and carted away by vandals. These wells had a very high potential of damage to the environment and reputational impact to the company due to the HSE exposure level, apart from not conforming to the Company's well integrity policy of a minimum of two (2) tested and independent barriers. The Well Integrity restoration team showcased various innovative ways which were applied in other to secure these wells safely, bearing in mind the non-existence of barriers for standard rig up of equipment for the securing operations. Integrity was successfully restored on the wells through the unconventional novel approach. The Heat treatment and NDT ensured integrity of the weld joints for safe rig up of the planned HWU for the abandonment.\u0000 This innovative approach prevented the potential process safety incident which could have led to asset, environmental and reputational damage. This paper would detail the history of the wells, planning, design and execution of the innovative in-house integrity restoration operation. The operation led to a total cost saving of US$1.8mln versus plan for the four vandalized wells that were restored.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"57 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":"134174983","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":"Innovative Approach to Identify PVT Regions in a Sandstone Reservoir in Khafji Field with Geological Events","authors":"K. Al-Qenae, Mohammed F. Alotaibi, L. Belazreg, Mohammad Akhtar","doi":"10.2118/213491-ms","DOIUrl":"https://doi.org/10.2118/213491-ms","url":null,"abstract":"\u0000 Prior to initiating a reservoir simulation study, the readiness of a complete set of fluid analysis data should be assured and quality checked. This usually includes, but not limited to, identification of any vertical and lateral variation of reservoir fluid properties. Identification of these trends can have tremendous impact on the results of the reservoir simulation project.\u0000 Recently, a reservoir simulation study was conducted on a brown reservoir in a Middle Eastern field. This reservoir is geologically characterized by various faults which were developed after fluid migration. The presence of these faults has resulted in communicated reservoir compartments. Application of traditional workflow in analyzing the PVT data was insufficient to identify any trend in the fluid properties or account for any vertical and lateral differences in reservoir fluid properties.\u0000 This paper explains the work done to characterize fluid properties for a structurally complex sandstone reservoir, where most of the downhole fluid samples were collected in the 1960s. Unfortunately, the sampling depth was not reported for most of the samples at that time, with no production logging data available to identify the production zones within the large perforation interval. Laboratory measurements indicate under-saturated oil with variation that could be correlated with depth. Samples were obtained from three geological subzones; Layers-1, 2 and 3, where a shale layer is believed to be partially separating Layer 1 from the other layers. Part of the challenge is that a large number of samples were collected from different sublayers as a combination, which increases sampling depth uncertainty.\u0000 Defining properties trend versus depth was the main challenge in the study. This uncertainty was addressed by developing an iterative \"what-if?\" analysis scenarios by integrating geological parameters. A new model was prepared that considered the initial conditions of the reservoir fluid before any migration or tectonic activities took place. Applying the proposed approach, resulted in a clear trend of hydrocarbon properties variation with depth and provided a clear observation of the presence of one PVT region in the reservoir. Based on the results of this study, one PVT region with a solution gas-oil ratio trend versus depth was applied into the reservoir model, which resulted in a reliable dynamic simulation model.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"24 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":"122821684","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":"Efficient Through-Casing Surveillance of Steam Chamber and Reservoir Oil Using a New Pulsed Neutron Technology and an Advanced Interpretation Algorithm","authors":"Yonghwee Kim, A. Kotov, D. Chace, Peng Yuan, T. Anniyev, F. Inanc, I. McGlynn","doi":"10.2118/213317-ms","DOIUrl":"https://doi.org/10.2118/213317-ms","url":null,"abstract":"\u0000 Steam flooding is an essential recovery process in developing heavy oil reservoirs. Operators typically drill and case observation wells to monitor the movement of the injected steam and changes in heavy oil and water saturations. This in-well surveillance is performed using pulsed neutron well logging techniques.\u0000 Pulsed neutron well logging technology has been used for more than 60 years to determine formation fluid saturation behind casing. We introduce a next-generation slim multi-detector pulsed neutron well logging tool. The new pulsed neutron tool integrates an upgraded pulsed neutron generator, lanthanum bromide scintillation detectors, and an improved electronics system.\u0000 A robust data analysis technique is another vital component of through-casing multiphase formation fluid quantification. A conventional method for analyzing three-phase saturation uses two pulsed neutron logs in sequence. We have adopted a simultaneous analysis approach that combines two pulsed neutron measurements simultaneously to evaluate the volumes of multiphase fluid components.\u0000 We present a case study of oil sands produced by the steam-assisted gravity drainage (SAGD) method. We also show comparisons of data acquisition with the previous-generation and new pulsed neutron tools, operating time, and data quality. We acquired time- and energy-based gamma-ray spectra from multiple detectors to extract key pulsed neutron measurements such as ratios of inelastic and capture gamma rays and carbon/oxygen ratios. Time- and energy-spectra-based salinity-independent nuclear measurements were combined to compute three-phase formation fluid saturation. The new tool acquired data of the same quality at least three times faster than the legacy tool. The new tool that offers three improved features (higher pulsed neutron outputs, denser scintillation detectors, and high-speed digital electronics) combined with a new acquisition technology that records time- and energy-spectra-based pulsed neutron data sets simultaneously enables faster reservoir surveillance.\u0000 Operators using thermal methods for heavy oil recovery must understand the current underground steam distribution. This affects steam injection optimization and determines subsequent reservoir management activities. A technique for delineating steam, heavy oil, and water through cased monitoring wells was improved by incorporating a new well logging tool, an innovative acquisition mode, and an advanced nuclear data analysis workflow.","PeriodicalId":249245,"journal":{"name":"Day 2 Mon, February 20, 2023","volume":"119 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":"128919313","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":"Geothermal Pre-Drilling Decision Optimization: Methodologies and Case Histories","authors":"W. Elsherbeny, K. Mccarthy, Taylor Mattie, Rakan Al-Murshed, M. Alshamry","doi":"10.2118/213251-ms","DOIUrl":"https://doi.org/10.2118/213251-ms","url":null,"abstract":"\u0000 Geothermal formations are hot, often hard, highly fractured and under-pressured. They often contain corrosive fluids and some formation fluids that have very high solids content. These harsh environments mean that drilling is usually difficult. Challenges include degradation of drilling fluids with associated variances in fluids properties, difficulty in managing mud systems, slow rate of penetration, short bit life and lost circulation. The potential for fines migration and induced formation damage in geothermal wells is significantly high due to weakening of attaching electrostatic forces under high temperatures and as a result of thermal contraction. Through case histories, this paper presents drilling challenges and the mechanisms of reservoir damages. The paper will also show the workflow and methodology of using the integrated geosciences analysis in pre-planning to mitigate the challenges related to geothermal activities.\u0000 Understanding geothermal reservoirs challenges requires a systematic workflow including but not limited to the following: structural geology, mineralogy, geochemistry, drilling fluid chemistry, high-temperature rock-water-fluids interactions, drill bit selection, and geomechanics modeling. ThermoChemo-Poroelasticity stability analysis is also an important consideration. Lab work to properly select the drilling fluids chemicals is required to optimize the drilling fluids parameters and simulating bottom hole temperature.\u0000 The outcomes from geology, mineralogy, geochemistry and geomechanics will be considered for optimum drilling fluids selection and fluids formulation optimization. The ultimate outcomes include but are not limited to MWT limits (Window), Breakout width, Pmud to trigger slip, drilling fluids formulation effects, drilling bits selection and surface parameters optimization.\u0000 For reliable performance in high-temperature environments, we need to consider the following: Know your geothermal reservoir; rock type, mineralogy, geochemistry, structural controls, geomechanics and Thermo/Chemo-Poro-elasticity conditions.Matching your injected water chemistry to formation water chemistry is very important, especially in high TDS geothermal brines. Incompatible total dissolved solids (TDS) concentrations will alter the ion carrying capacity, disturb the natural reservoir equilibrium and can lead to formation damage.Optimizing drilling fluid selection.Hydraulics, gel breaking, swab and surge including thermal effects.High-performance drill bits to keep you in the hole longer, reducing trips and saving you moneyAdvanced drilling technologies to deliver fast, efficient wellbore construction, including specially engineered motors for extreme operating environments, automated drilling systems, and high-temperature MWD technologies.","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":"128653023","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}