Day 2 Tue, March 14, 2023最新文献

{"title":"First Application of a Novel Self-Healing and CO2-Resistant Cement on a Deepwater Cementing Operation","authors":"C. Azwar, R. Kusumawatie, Anwar Faizd Osman, Bipin Jain, V. R. Wedhaswari, Andre Simanjuntak, Agung Arya Afrianto, Y. R. C. Siregar, Andrean Firnanto","doi":"10.2118/214110-ms","DOIUrl":"https://doi.org/10.2118/214110-ms","url":null,"abstract":"\u0000 Harbour Energy began offshore exploration in the Andaman Sea in North Sumatra, Indonesia with the Timpan-1 well. During the planning phase, reservoir sections of the well were identified that contained circa 5-15% of CO2 levels as per the offset well data, which are corrosive environments and can cause cement sheath degradation. This paper presents the decision process used in selecting a suitable system for the CO2-rich environment and the first-time application of pumping novel self-healing and CO2-resistant cementing system with its capability to self-heal upon contact with CO2.\u0000 Conventional Portland cement degrades in CO2-corrosive environments and combined with cement sheath damage by downhole stresses, long-term well integrity will be compromised. The auto repair capabilities provided by the novel cement system when in contact with CO2 leaking-fluids ensure long-term well integrity. Although self-healing-to-hydrocarbons cements have been widely used in the industry, use of this newly developed novel self-healing CO2-resistant cement was implemented for the first time in a primary casing job. To ensure blend consistency of the novel self-healing CO2-resistant cement, a number of quality control processes were developed with extensive laboratory testing and implemented for the complete blend lifecycle management.\u0000 Implementation of this novel self-healing CO2-resistant cement in a deep-water primary casing job requires validation of crucial factors meet the requirements of achieving the long term well integrity. During the preparation phase, this cementing system was exposed to a high-CO2 corrosive environment over an extended period to analyze the robustness. The results showed superior properties compared with a conventional Portland system. The self-healing properties, analyzed with the use of an actual crack in the set cement and observed to the point where the crack closed, demonstrated continued cement integrity. Slurry stability tests produced excellent results. Blend flowability and robustness tests were performed at a regional laboratory using specialized equipment and determined the blend to be suitable for offshore operations. In implementation phase, by adhering to the project management process developed, the primary casing cement job was successfully performed without incident using conventional cementing equipment and practices. Good cement bond was obtained across the main zone, and the rig was able to continue its operations to perforate and well test the well.\u0000 The 2001 Greenhouse Gas (GHG) Protocol's guidelines categorized business GHGs as scope 1 emissions, scope 2 emissions, and scope 3 emissions. The aim of this emission classification system was to help organizations measure and manage their carbon footprint (www.greenbusinessbureau.com 2022). Scope 1 emissions are GHGs released directly from a business. Scope 2 emissions are indirect GHGs released from the energy purchased by an organization. Scope 3 emissions are a","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"39 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124451601","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":"Data Science Techniques for Unbiased & Efficient Production Analysis","authors":"C. Jordan, R. Koochak, Martin Roberts","doi":"10.2118/214146-ms","DOIUrl":"https://doi.org/10.2118/214146-ms","url":null,"abstract":"\u0000 Analyses have been widely applied in production forecasting of oil and gas production in both conventional and unconventional reservoirs. In order to forecast production, to estimate reservoir properties, or to evaluate resources, various statistical and machine learning approaches have been applied to various reservoir analysis methods. Nevertheless, many of these methods are suboptimal in detecting production trends in different wells due to data artifacts (noise, data scatter and outliers, inadequate SCADA systems, production allocation problems) that obscure unit reservoir signals, production trends, and more leading to large forecast error, or fail due to lack of data access (inadequate SCADA systems, missing or abhorrent data, and production allocation problems). This work outlines a method that is currently being used in a commercial setting which combines advanced analytics and machine learning with a modern cloud architecture, provide rapid, repeatable, unbiased estimates of original hydrocarbon -in-place (OHIP), estimated ultimate recovery (EUR), and remaining recoverable (RR), and even deliverability forecasts - all in the presence of abhorrent data.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"141 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124496881","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":"Understanding Your Wells: Conventional Nodal Analysis; Not a Solution for Depleting Fields","authors":"H. Ahmed, Sohail Ahmed Mallah, Muhammad Talha Anwar, Muhammad Ali, Syed Dost Ali, W. Javed, Muhammad Usman","doi":"10.2118/214230-ms","DOIUrl":"https://doi.org/10.2118/214230-ms","url":null,"abstract":"\u0000 Modeling fluid behavior using conventional nodal analysis software is a common practice in the oil and gas industry. However, understanding flow physics helps production engineers to understand the difference between predicted and actual flow behavior. This work presents a methodology applied to a depleting oil and gas field in northern Pakistan. The adopted approach not only helped to overcome vertical lift performance issues in the wellbore, but it also resulted in improved and sustained oil and gas production from the well. Based on these results, wells in the field with vertical lift performance issues were identified and evaluated using the analysis approach presented in this work.\u0000 Basic petroleum engineering concepts are implemented using a multi-tier approach, and a proposal was outlined to understand the sluggish flow behavior from the well. The analysis approach characterizes the problem as \"IPR dominated\" or \"VLP dominated\" flow using the well's historical data and nodal analysis results, identifies the requirement for a new data set, and then operations are planned accordingly. During execution, coil tubing with memory gauges was deployed with a provision to simulate Coil Tubing Gas Lift (CTGL) with single point injection. This arrangement not only resulted in sustained production from the well, but it also provided leverage to gather bottomhole data corresponding to multiple flow parameters during sensitivity analysis.\u0000 The workflow explains the physics behind oil and gas wells with sluggish liquid production and the inadequacy of conventional nodal analysis software in predicting production rates with certainty. The application of this workflow converted a \"sick well\" into a \"sustained production well,\" which was previously ruled out for the implementation of ALS techniques during initial screening using conventional nodal analysis software.\u0000 This novel approach highlighted the \"domain of applicability\" of conventional nodal analysis software and proposed a detailed workflow for artificial lift candidate selection. This workflow served as the blueprint for the overall evaluation of well productivity in depleting fields with VLP issues.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"125 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117263067","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":"Keys for Success to Deliver and Strengthening a Sustainable Safety Culture in Developing Companies in Developing Countries Facts about Safety Culture, Facts About Safety Culture?","authors":"Wael Mohamed Amin","doi":"10.2118/214259-ms","DOIUrl":"https://doi.org/10.2118/214259-ms","url":null,"abstract":"\u0000 What is a safety culture? There are many contemporary definitions of safety culture, most are taken from the one giving by advisory committee on safety back in the 1980’s which states :-- The product of individual and group values, attitudes, competencies, perceptions and patterns of behavior that determines the commitment to, and the style and proficiency of an organization’s health and safety management.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"85 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128385713","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 Approach for Estimating Formation Permeability in a Highly Heterogeneous Reservoir in Middle East","authors":"R. Celma, A. Lavenu","doi":"10.2118/214098-ms","DOIUrl":"https://doi.org/10.2118/214098-ms","url":null,"abstract":"\u0000 Estimating flow in the reservoir is critical for production forecasting, 3D modeling and field development. Laboratory experiments are the main source of information for the permeability, but the results might be impacted by a high degree of reservoir heterogeneity, as well as by the upscaling from core to log. The studied reservoir displays a complex lithology — limestone and dolomite – where dolomitization appears to be a clear reservoir rock quality enhancer. High permeability streaks can be related to dolomitized intervals, however a simple porosity vs. permeability function cannot capture the large variation of this property (from 0.1 to 5000mD)\u0000 In this study, the volumetrics computed from a comprehensive petrophysical model that includes the integration of core descriptions, XRD, and gamma ray spectroscopy to properly estimate the fractions of limestone, dolomite, clay, and heavy minerals were used. A core to log correlation was made and it clearly showed how the dolomitization improves our reservoir properties, in particular the permeability. Trends functions were established based on the stratigraphy and on the content of limestone/dolomite. These trends were used to train a fuzzy logic model supported by other logs such as: normalized porosity and density-neutron vector angle/length. The vector angle/length are coordinate transforms to convert neutron density into linear independent vectors.\u0000 This approach addresses the large variation of permeability related to the strong diagenetic footprint onto the reservoir. The results were compared to permeability from core and KH from PTA analysis, and displayed an error of less than 5%","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":" 33","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"113952833","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":"Well Logs Interpretation Using Machine Learning Workflow","authors":"Zainab Al-Ali Hussain Al-Ali","doi":"10.2118/213986-ms","DOIUrl":"https://doi.org/10.2118/213986-ms","url":null,"abstract":"\u0000 Well logs are used to measure acoustic, nuclear, or conductive properties of the subsurface. In turn, these properties are interpreted based on some physical correlations to compute essential reservoir characteristics such as porosity and water saturation. Most of these physical calculations require a pre-knowledge of the reservoir fluid and rock properties as well as domain knowledge experts and petrophysicsts. This process could also be time consuming and inconsistent due to measurement anomalies and expertise bias. Recent advances in artificial intelligence have produced a paradigm shift in the industry from using traditional physics-based methods to adopting modern data-driven models to reduce physical complexity, improve speed and accuracy. Many research aspects are now focused towards using machine and deep learning models to improve well logs analysis covering many aspects including: detecting anomalies, classification of lithology and automated prediction of reservoir parameters. This paper presents a modern approach of using machine learning modeling workflow for well log interpretation combining both unsupervised and supervised learning technique. The presented model is capable of efficiently predicting several reservoir properties including, water saturation, volume of shale and porosity, without the pre-knowledge of complex physical rock and fluid characteristics.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"121 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131510600","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":"Interactive Analysis (IRA) Determining Focal Reservoir Parameters Dominating Estimated Ultimate Recovery (EUR)","authors":"Youngbin Shan, Yaoguang Wu, A. Hu, Fanlei Li","doi":"10.2118/214115-ms","DOIUrl":"https://doi.org/10.2118/214115-ms","url":null,"abstract":"\u0000 Interactive Analysis (IRA) is a new reservoir study method which applies to both condensate oil & gas reservoir and conventional oil & gas reservoir.\u0000 IRA establishes the correspondence between stage EUR equivalents and reservoir parameters.\u0000 Often, reservoir parameters include but not limited to porosity, permeability, burst pressure, Poisson rate, Oil saturation or Gas content, Free gas content and adsorption gas content, pay zone thickness, resistivity, mud content, etc.\u0000 In a specific compartmentalization, it is important to decide which parameter is the focal parameter dominating the productivity. If the focal parameters can be decided, operators can use this evidence to decide which zone and which sub-zone drilling must fully penetrate through. Additional, when well is designed for hydraulic fracturing, engineers can use this data to design stages and clusters. Designing of higher focal parameter quality in stage and cluster is certainly a contribution to better frac efficiency and EUR.\u0000 IRA is expressed that the Normalized Correlated Coefficient (NCC) Vector is equal to the Moore-Penrose inverse of the Normalized Reservoir Parameter Quality Factors (NRPQF) matrix multiplying the Normalized EUR equivalent (NEE) vector. NCC deriving from the IRA represents the weight of productivity contribution to EUR.\u0000 Analyzing IRA equation, the focal parameters dominating the well EUR can be determined. With focal parameters available, operators can optimize the drilling criteria and optimize frac design.\u0000 For a specific compartmentalization, the focal parameters derived from IRA shall give consistent focal parameters which dominate the higher productivity and lower productivity. When a well is hydraulic fractured, the NEE can be tested and analyzed. To input the NEE into IRA equation, the frac efficiency is also reflected by NEE.\u0000 Three shale gas wells in a compartmentalization are analyzed via IRA analysis. The positive focal parameters, irrelevant parameters and negative focal parameters in each well and overall averaging give good convergence.\u0000 Two wells in condensate oil pay zone in a compartmentalization are also analyzed via IRA analysis. The positive focal parameters, irrelevant parameters and negative focal parameters in each well and overall averaging give some convergence.\u0000 If a NCC is bigger, it dominates EUR. If it is small or very small, the contribution to EUR is less or measily. On the other hand, if a NCC is positive, it increases the productivity when the parameter quality is higher. If a NCC is negative, it decreases the productivity when the parameter quality is higher.\u0000 No focal parameter dominating EUR can be understood until IRA is proposed.\u0000 Rather than reservoir mechanics analysis, IRA gives explicit linear mathematical expression which makes engineers easier to calculate by aid of Matlab coding.\u0000 IRA analysis is a breakthrough to understand the intrinsic structure between reservoir parameters and EUR.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"32 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123813978","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":"Breaking New Ground. Enhancing Polycrystalline Diamond Compact (PDC) Bit Performance in Chert Formations through Use of Shaped Cutter Technology","authors":"Mohamed Abdelrazik, A. Ismail, Ahmed Suleiman, Hatem Hanafy","doi":"10.2118/214145-ms","DOIUrl":"https://doi.org/10.2118/214145-ms","url":null,"abstract":"\u0000 Cherty formations are notoriously challenging for fixed cutter drill bits and present a costly challenge for operators who routinely experience short intervals and numerous trips. The predominant limitation is short bit life due to mechanical failure of the cutters. This paper details how an inter-company collaboration led to the development of a design philosophy and a novel shaped cutter technology that resulted in a step change in drilling efficiency and drilling consistency in chert formations.\u0000 A collaboration between companies was initiated that commenced with a comprehensive study into the cutter-rock interaction to identify the failure mechanism of chert. The results of the research were then used to determine the critical design levers required to overcome these challenges, extended bit life and maximize drilling efficiency. Two fixed cutter drill bits in the 6-in. and 8.5-in. hole sizes that incorporated the new design philosophy and shaped cutter technology were designed. These bits were then field tested in the Egypt Gulf of Suez interbedded carbonates application characterized with the presence of dark brown chert.\u0000 The new 6-in. and 8.5-in. designs were tested twelve times across four different fields. The runs were then evaluated against durability, rate of penetration (ROP) and cost per foot (CPF) compared to field offsets. In the 6 in. section, the new design drilled the entire section of 3,369-ft that includes 381-ft cherty formation with one bit compared to three bits previously required to drill the same interval. For the same offsets, an improvement of between 50-85% in ROP was achieved. The CPF assessment demonstrated drilling cost reduction between 24-75% across the fields tested. In the 8½ in. section, the new design drilled the entire section of 6,141 ft that includes 296-ft cherty formation with one bit compared to four bits previously required to drill the same interval. ROP wise, an improvement between 59-178% was achieved which corresponded to a CPF reduction of between 41-69% across the fields tested. These field tests demonstrate ground-breaking results in the durability, ROP and CPF performance metrics measured. Furthermore, the number of runs and diverse nature of the fields tested demonstrate the consistency of this new approach to drill cherty formations with full directional control and mitigating downhole vibration severity.\u0000 A re-examination of the failure mechanism of chert drilling and the root cause behind drilling deficiencies in cherty applications conducted in a collaborative environment has paved the way for a step change in drilling performance. Novel design philosophies were created, laboratory tested, and field validated for consistency of the trials. As the drilling industry continues to explore unchartered applications to ensures cost efficient solutions is paramount to success","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"104 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134473417","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":"Characterization of Tight Sandstone Reservoir Pore Structure and Validity from Geophysical Logging Data by Using Deep Learning Method","authors":"Gao-ren Li, Wei Zhang, Die Liu, Jing Li, Cheng Li, Jiaqi Li, Liang Xiao","doi":"10.2118/214124-ms","DOIUrl":"https://doi.org/10.2118/214124-ms","url":null,"abstract":"\u0000 Pore structure described the macroscopic pore size and microscopic pore connectivity. It heavily determined formation quality and seepage capacity, and thus associated with permeability. Generally, ultra-low permeability to tight sandstone reservoirs were always affected by complicated pore structure and strong heterogeneity. Characterizing pore structure was of great importance in improving tight sandstone reservoir evaluation and validity prediction. Nuclear magnetic resonance (NMR) logging was considered to be valuable in pore structure prediction only in exploration wells because plenty of NMR logging data was acquired in key wells. However, methods that established in exploration wells cannot be directly extended into development wells due to the limitation of quantity of NMR data. In addition, NMR logging was only usable in pore structure characterization in water saturated layers, it cannot be directly used in hydrocarbon-bearing reservoirs. In this study, to establish a widely applicable pore structure characterization method that can be used not only in exploration wells, but also available in development wells to improve formation validity evaluation and high-quality formation identification in Triassic Chang 8 Formation of Shunning Region, Eastern Ordos Basin, we established a technique to synthetize pseudo-Pc curve from geophysical logging data by using deep learning method. This technique was raised based on the morphological feature analysis of mercury injection capillary pressure curves. We found that the applied mercury injection pressures were the same for all core samples during mercury injection experiments, the pore structure difference for all core samples was determined by injected mercury content (SHg) under the same Pc. Hence, once we predicted mercury content under every Pc, pseudo-Pc curve can be synthetized by combining predicted mercury content and known Pc. Constructing pseudo-Pc curve was translated as predicting mercury content. To establish a reasonable model that can be used in development wells, where only conventional logging data was available, we analyzed relationships among mercury contents under every mercury injection pressure and geophysical logging data. This analysis was raised based on heat map of decision tree technique, and the experimental data of 115 core samples that drilled from Triassic Chang 8 Formation in Shunning Region was used. Finally, we found that SHg under 15th capillary pressure was heavily related to porosity and deep and shallow resistivity. Based on this perfect relationship, we established a model to predict 15thSHg from porosity and deep and shallow resistivity by using deep learning method of XGBoost. In this deep learning method, 92 clusters of core analysis data (accounting for 80.0% of the total), were used as training samples, and the rest 20.0% was retained as samples for verification. Meanwhile, relationship between SHgs under two adjacent mercury injection pressures was a","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"18 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133559627","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":"Multi stage Frac & Testing of High Angle HPHT Ultra Sour Exploratory Well: Challenges Encountered & Mitigated","authors":"Saad Abdullah Al-Dosari, A. Al-Ateeq, Akash Ranjan, A. Salem, Saurabh Asthana, L. Peiwu","doi":"10.2118/214156-ms","DOIUrl":"https://doi.org/10.2118/214156-ms","url":null,"abstract":"\u0000 Reservoir production challenges are always escalated when the concentration of H2S and CO2 are extremely high. This paper highlights the challenges encountered, mitigation techniques used to overcome hurdles, and remaining tasks in testing the first deep high angle High Pressure High Temperature (HPHT) exploratory well completed with Multi-Stage Completion (MSC) in the presence of ultra-sour fluid (H2S-31% and CO2-38%) in Kuwait.\u0000 The subject Jurassic well is drilled at a highly deviated angle up to 19,000 ft in measured depth (MD). The completion installed is composed of an open-hole MSC and three stages of frac ports tied back with a Liner Hanger to the upper 4.5 inch tubing. After setting the completion, the 15.8 ppg oil base mud (OBM) completion fluid was displaced with 11.6 ppg brine. DataFrac treatment and analyses were followed by acid fracturing treatment in all three stages. Post-fracturing well clean-up is achieved by continuously pumping Hydrogen Sulfide (H2S) scavenger to protect the entire surface test equipment set up. Employing self-containing breathing apparatus for personnel safety and having two flare pits permitted uninterrupted well testing for 13 days.\u0000 During the well clean-up, the very high H2S and Carbon Dioxide (CO2)concentrations in knocked out fluid were 31% and 38%, respectively. However, due to the extremely high sour nature of reservoir fluid and limitation of separator metallurgy, the flow rate measurement is limited to only 2 hours. Various technical and operational safety challenges were safely handled during the well preparation, acid fracturing, testing, and flaring operation without any HSE incident. Moreover, continuous flow rate measurements are not achieved due to equipment limitations. Currently, a multi-phase flow meter (MPFM) which can handle high H2S and CO2 is under evaluation to conduct long term well testing to ascertain the production potential.\u0000 The completion of three stage acid fracturing treatments and safely testing the high sour deviated well in HPHT conditions of an exploration well for the first time in the State of Kuwait is a remarkable success, paving the way for future field development in similar well conditions. However, production and processing of this highly sour fluid will be challenging for field development.","PeriodicalId":349960,"journal":{"name":"Day 2 Tue, March 14, 2023","volume":"199 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-03-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115718244","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}