Day 1 Wed, March 13, 2024最新文献

{"title":"Analysis of Energy-Economic Dynamics in Canadian Provinces: Insights from Data Analytics","authors":"K. Gbakon, J. A. Ajienka, O. Iledare, J. Gogo","doi":"10.2118/218109-ms","DOIUrl":"https://doi.org/10.2118/218109-ms","url":null,"abstract":"\u0000 This paper conducts study of the relationship between end-use energy demand and economic growth as indicated by the Gross Domestic Product (GDP) on a province-level within Canada. There is abundant literature investigating the direction of causality between energy use and economic growth. However, these studies tend to focus on country units or groupings of countries. Additionally, the direction of causality between energy and economic growth has yielded mixed results, which depend on the econometric methods used, the time period, and the inclusion of other economic growth/productivity factors, such as labour and capital. The contribution which this paper seeks to make is to determine the relationship between GDP and energy use within the sub-national units of Canada. This is especially important to help shape the broader conversation about the potential distributional impact of climate change policies on the economic well-being of the sub-nationals of Canada. This paper utilizes the well-known Cobb – Douglas functional form to examine the relationship between inputs, end-use energy demand, and output, defined as GDP for the provinces. Population, End Use Energy Demand and provincial level GDP time series data from 1995 to 2021 are obtained from StatsCan. Our descriptive data analysis revealed that the highly ranked provinces by growth rate of energy use per capita were not necessarily top ranking by GDP per capita growth rate. Taken together, since year 2000, 10 of out of Canada’s 13 provinces and territories have achieved growth in GDP per capita while reducing their Energy use per capita. Additionally, Granger causality showed broadly that the sub-nationals of Canada can be classed majorly as either having neutral relationship between energy and economic growth (46%) or are in the category where economic growth drives the energy use per capita (39%).","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"39 3","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140284666","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":"Tight Gas Production Prediction in the Southern Montney Play Using Machine Learning Approaches","authors":"Gang Hui, Fuyu Yao, Zhiyang Pi, Penghu Bao, Wei Wang, Muming Wang, Hai Wang, Fei Gu","doi":"10.2118/218115-ms","DOIUrl":"https://doi.org/10.2118/218115-ms","url":null,"abstract":"\u0000 Recently, the machine learning approach has been used to forecast tight gas production from unconventional resources. However, the performance of machine learning-based predictive models has not been successful with respect to actual field production. The poor performance has been ascribed to several factors, including the relatively few field data and few input data from geological, geomechanical, and operational information. This study uses big data analytics to develop a prediction model for Southern Montney Play in the province of British Columbia, Canada. First, a complete dataset is built, including ten geological, geomechanical, and operational characteristics for 3146 horizontal wells in Southern Montney Play. Then, the relationships between the first-year production and input parameters are evaluated, and controlling factors are identified. Finally, a comparative study of prediction models with distinctive training algorithms is conducted to find the best algorithm for predicting first-year production. The results reveal that the top features that contribute most to tight gas productivity are total injection volume, porosity, and formation pressure. Features with secondary effects are net thickness, fracturing depth, and number of stages. The other features, including permeability, gas saturation, horizontal length, and cumulative proppant injection, are the least related. The Random Forest algorithm with the highest correlation coefficient (R2=0.82) and lowest mean absolute error (MSE=0.15) is picked. The Random Forest-based production prediction matches the observed field production, indicating that the northeastern portion of the study area has the highest estimated tight gas productivity. This procedure can be applied to additional scenarios involving tight gas production and used to guide the future site selection and fracturing job size, thereby achieving effective tight gas development.","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"48 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140394839","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":"Enhancement of Oil Production in an In-Situ Combustion Process through Unconventional and Innovative Approaches: Case Study from Lanwa Field, Cambay Basin, India","authors":"Ankush Kumar, Rakesh Kumar, Anshul Kesharwani, Jnanaranjan Mahanta, Nitesh Kumar Jain, S. K. Khadia, H. S. Dayal","doi":"10.2118/218064-ms","DOIUrl":"https://doi.org/10.2118/218064-ms","url":null,"abstract":"\u0000 The objective of the paper is to demonstrate the 30% rise in oil production through unconventional and innovative methods in a heavy oil field \"Lanwa\" (oil viscosity: 1000-1500 cP) supported by active edge water drive. The non-conventional techniques involves, Water shut off (WSO) with Gravel pack in place, Aquifer management by flue gas trapping, Optimization of air injector- producer combinations in ISC affected areas and restoring the productivity of 6 horizontal wells through foam jobs by Coiled tubing. These efforts were made by revisiting the existing practices and improved technical understandings of the field. Results of field implementation of these activities helped in increasing the oil production of the field by ~ 62 m3/day.\u0000 Water Shut Off (WSO) is being done to reduce the effect of water fingering due to adverse mobility in Lanwa field. Conventionally, WSO jobs were done by fishing out the Gravel pack (GP) assembly followed by polymer squeeze, Zone optimization and reinstalling the GP. To avoid the complicated workover operations, Rigless polymer squeeze through Gravel pack was experimented and desired reduction in water cut is observed. The rigless polymer squeeze resulted in reduction in water cut to 60% from 90-95% and remained low for 1.5-2 months and in some cases for a longer duration. The new process of WSO is very easy to execute and requires very less expenses which facilitates the increased number of WSO jobs. The number of annual WSO jobs in the field increased by 8 times. A total of 35 jobs were carried out in a year and resulted in incremental gain of 20 m3/day of oil.\u0000 Insitu combustion process in part of the field is operational since 2010. Idea of trapping the flue gas to form a secondary gas cap to counter the aquifer encroachment was tested by closing/reducing bean size in high GOR wells. Flue gas production was reduced by 50%, which helped in expansion of secondary flue gas cap which in turn resulted in reduced aquifer activity in extremely adverse mobility conditions. Around 22 m3/day of oil gain has been observed in 4 oil producers along with the stability of water cut in down dip wells.\u0000 To capture the mobilized oil from the ongoing ISC process, air injector to producer distance was optimized through shifting of injectors. Drain hole of the horizontal producers were cleaned by rigless foam jobs through Coiled tubing which resulted in regaining the productivity of horizontal wells. Optimizing the injector to producer distance and productivity improvement in horizontal wells resulted in oil gain of 20 m3/day.\u0000 Performance of Insitu combustion process can be improved by trapping the flue gas and by proper placement of air injectors. Issue of circulating fluid loss while clearing the drain hole can be eliminated by the use of foam as circulating fluid during Coil Tubing operation (CTU-Foam). As the performance of water shut off with GP inplace was found encouraging, the same can be done through rig-less approach.","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"25 2","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140284873","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":"Adapting Corporate Strategies for Energy Transition: A Case Study on Production Liability Management","authors":"E. Orozco, W. Caro","doi":"10.2118/218026-ms","DOIUrl":"https://doi.org/10.2118/218026-ms","url":null,"abstract":"\u0000 This article analyzes what effects a transition from hydrocarbon investments to renewable alternatives may have on Well Integrity, identifying how organizational changes are required to maintain regulatory compliance and the management of legal and financial responsibilities associated with the production of oil and natural gas., the correct management of risks associated with assets in production and the mitigation of environmental impacts.\u0000 It is determined through an analysis from the point of view of market margins, incentives, advantages and disadvantages in which O&G organizational area between upstream, midstream and downstream the management functions of investments in renewable alternative energies should focus.","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"15 5","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140284972","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":"Prediction of Mineralogical Composition in Heterogeneous Unconventional Reservoirs: Comparisons Between Data-Driven and Chemistry-Based Models","authors":"Zhengru Yang, A. Ghanizadeh, A. Younis, C. R. Clarkson","doi":"10.2118/218116-ms","DOIUrl":"https://doi.org/10.2118/218116-ms","url":null,"abstract":"\u0000 Prediction of mineralogical compositions along multi-fractured horizontal wells (MFHWs) using indirect methods, for the purpose of characterizing lithological and rock brittleness heterogeneity, is appealing due to the challenges associated with direct mineralogical evaluation. This study aims to 1) develop predictive machine learning models for indirect estimation of mineralogical compositions from elemental compositions, 2) compare mineralogical compositions obtained from data-driven and chemistry-based approaches, and 3) provide practical recommendations for fine-tuning and training of data-driven models.\u0000 Leveraging recent advances in deep learning, an attention-based gated recurrent unit (AttnGRU) with a \"feature extractor-post processor\" architecture was developed for predicting compositions of ten primary minerals based on elemental data. For comparison, classic regression-based and ensemble learning models including support vector regression (SVR), random forest (RF), and a feedforward neuron network (FFNN) were utilized. Data-driven models were trained and tested using XRD data measured on 217 samples from the Montney Formation, and the outcomes were compared to those derived from stoichiometric material balance equations (a previously-developed chemistry-based model) to evaluate the effectiveness and capabilities of different predictive approaches.\u0000 The data-driven models consistently outperformed the chemistry-based method with significantly lower mean absolute error (MAE) and higher R2. The predictive performance order was FFNN ≥ AttnGRU > RF > SVR >> chemistry-based model, with MAE = 1.05, 1.09, 1.24, 1.35, and 2.46 wt.%, respectively. Importantly, FFNN, AttnGRU and RF offered more accurate predictions of chlorite and illite, which are known to negatively affect reservoir quality. This indicates the superior performance of the three models for reservoir characterization applications. Furthermore, AttnGRU exhibited greater robustness than the other two models, with less sensitivity to overfitting issues. Data-driven models displayed different levels of performance when decreasing training dataset size. It is recommended that, in order to achieve reasonable predictions for the studied reservoir with data-driven approaches, more than 50 training samples be used. It is further observed that data-driven models exhibited limited predictive capability (MAEs ranging from 3.02-3.45 wt.%) when applied to a synthetic \"global dataset\" comprised of samples from various formations.\u0000 Through the comparison of multiple independent datasets (XRF-derived chemistry-based, XRF-derived data-driven, XRD) collected on identical samples, this work highlights the strengths, limitations, and capabilities of different machine learning techniques for along-well estimation of mineralogical composition to assist with reservoir characterization.","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"100 9","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395476","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":"Characterizing Fluid Flow in Multizone Reservoirs: Integrating Petrophysical Logging with Pressure Transient Responses","authors":"Saunil Rajput, S. T. Nukala, T. B. Wydiabhakti, Abhimanyu Singh, Velerian S. Lopes, Arvind Kumar, Keka Ojha","doi":"10.2118/218112-ms","DOIUrl":"https://doi.org/10.2118/218112-ms","url":null,"abstract":"\u0000 The realm of numerical modeling in hydrocarbon reservoir management has evolved dramatically with the advent of multilayer pressure transient modeling, a technique that has revolutionized the analysis and prediction of fluid flow in subsurface formations. This paper delves into the intricate aspects of multilayer pressure transient modeling, highlighting its significance and the transformative impact it has on numerical modeling in reservoir engineering.\u0000 At its core, multilayer pressure transient modeling is an advanced method that allows for the detailed simulation of pressure behavior in multi-strata reservoirs. These reservoirs, characterized by their heterogeneity and complex interlayer dynamics, pose significant challenges in terms of accurate prediction and management. Traditional single-layer models often fall short in capturing the nuanced interactions between different strata, leading to less accurate forecasts and suboptimal reservoir management strategies.\u0000 The review begins by establishing the fundamental principles of pressure transient analysis (PTA) in reservoir engineering, setting the stage for understanding the nuances introduced by multilayer configurations. It then methodically transitions into the specifics of multilayer modeling, discussing the mathematical and computational frameworks that underpin this approach. The discussion includes the implementation of various numerical methods such as finite difference, finite element, and boundary element methods, each offering unique advantages in handling the complex geometry and flow dynamics of multilayer reservoirs.\u0000 A pivotal section of the review is dedicated to the practical applications and benefits of multilayer pressure transient modeling. One of the key advantages is the enhanced ability to interpret pressure data from well tests accurately. This capability is crucial for reservoir characterization, allowing engineers to infer properties such as permeability, porosity, and fluid saturation levels across different layers. The improved resolution in data interpretation directly translates to more effective reservoir management strategies, optimizing hydrocarbon recovery while mitigating risks associated with overproduction or inefficient resource utilization.\u0000 Another significant aspect covered in the review is the role of multilayer pressure transient modeling in supporting enhanced oil recovery (EOR) techniques. By providing a more detailed understanding of interlayer flow dynamics and pressure interactions, this modeling approach aids in designing more effective EOR strategies, particularly in heterogeneous reservoirs where conventional methods may not be as effective.\u0000 The review also addresses the integration of multilayer modeling with other reservoir simulation tools and techniques, such as history matching and geostatistical analysis. This integration is crucial for developing a comprehensive understanding of reservoir behavior, leading to more accurate forecast","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"69 4","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395569","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":"Coupled Geomechanical Model and 3D Dynamic Flow Simulation for the Potential CO2 Injection into Deep Aquifer Siluro-Devonian Carbonate Formations, Delaware Basin","authors":"S. Nguyen, J. Tu, T. Nguyen, W. Ampomah, J. Simmons, D. Bui","doi":"10.2118/218069-ms","DOIUrl":"https://doi.org/10.2118/218069-ms","url":null,"abstract":"\u0000 One of the main foundations for increasing trust in geological carbon dioxide (CO2) sequestration is a geomechanical application. A complex geological process for long-term CO2 storage in deep aquifer carbonate formation would irreversibly change the assumed stable state of the sedimentary basin that evolved over millions of years. The proposed project is expected to sequester 13 MMSCFD of CO2 and H2S into Devonian and Silurian formations deeper than 16,000 feet below Lea County in New Mexico's Delaware Basin, a sub-basin of the Permian. The intensive integration of geomechanical parameters and 3D flow simulation can provide insights into storage mechanisms, migration patterns and effects on caprock integrity over 30-year injection and 100 years of shut-in.\u0000 This research illustrates the comprehensive development of a 3D structural framework on interpreted surfaces and spatial variability of porosity and permeability. The dynamic flow is subsequently furnished with the boundary parameters of relative permeability, geochemical fluid components, temperature, pressure, and injection rate to simulate gas accumulation and diffusion trends. Furthermore, the findings of geomechanical rock properties and strengths are incorporated into the dynamic model to evaluate further the impact of CO2 flow on Woodford caprock stability across injection and shut-in times.\u0000 Through 3D dynamic simulation, it is estimated that gas storage could reach 7.04 million metric tons with a maximum daily injection rate over the course of 30 years. The gas plume would migrate around 834 acres in the planned sequestration zone, or a radius of 0.64 miles from the injection well. The coupled geomechanical model and CO2 flow assist in exploring the caprock failure on Mohr-Coulomb circle analysis, shear, and tensile safety factors in both spatial and time dimensions of dynamic flow simulation. Despite the thermal effects, stress changes, and geochemical interactions that occur over the injection period, the caprock retains its elastic modulus and is assessed to be far from failures.\u0000 The study involves solving equations of motion and stress-strain relationships to determine how the caprock will respond to changes in pressure and fluid flow. The exceptional durability of Woodford Shale seal rock will promote the success of the CO2 storage in aquifer Siluro-Devonian carbonate rocks underneath New Mexico and pave the solid way for further long-term CO2 injection wells across the Delaware Basin in the coming decades.","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"25 7","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140285060","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":"Geomechanical Modeling and Minimum Fracture Pressure Prediction of CO2 Storage Reservoir Caprock in the Lloydminster Area","authors":"Chen Shen, Ze Li, Yuanhao Chang, Baoxin Zhang, Fanhua Zeng","doi":"10.2118/218080-ms","DOIUrl":"https://doi.org/10.2118/218080-ms","url":null,"abstract":"\u0000 Acknowledging the critical imperative to reduce CO2 emissions globally, there is a heightened drive towards adopting the preferred CCUS technology to achieve sustainable greenhouse gas reduction. CCUS requires a reliable caprock integrity to prevent CO2 migration and ensure the success of the injection program. Nevertheless, the impact of mineralogical alterations on caprock integrity continues to elude comprehensive understanding through research. This study investigates the evolution of caprock integrity resulting from long-term CO2 storage-induced mineralogical changes. A 2D Voronoi model is developed to predict the minimum fracture pressure of sideritic shale caprocks with varying mineral compositions in the Waseca heavy oil formation, Canada. The numerical simulations are validated against geomechanical test results, showing good agreement. Sensitivity analysis reveals visible variations in the plastic deformation process due to CO2-water-rock reactions and mineral transformations. Results indicate that caprocks with higher hard minerals, such as quartz, exhibit higher minimum fracture pressures. Additionally, positive interactions between siderite and feldspar intensify cementation within the pore structure. This study provides valuable insights into the mineralogical change effects on caprock integrity and offers a reliable framework for assessing caprock integrity during long-term CO2 storage.","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"114 12","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140394932","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":"Physical Simulation of Primary Production in Duvernay Shale – Impact of Thermal Maturity on Oil Production","authors":"Amin Alinejad, Hassan Dehghanpour","doi":"10.2118/218030-ms","DOIUrl":"https://doi.org/10.2118/218030-ms","url":null,"abstract":"\u0000 Most unconventional wells typically exhibit limited oil production during the primary production stage, primarily due to ultralow permeability of the rock matrix and immaturity of the organic matter. To understand the key factors responsible for this limitation and identify candidate sweet spots for drilling, we conduct physical simulations of the primary production stage in the laboratory. In this study, Duvernay shale samples undergo a single-cycle methane injection process to simulate the primary production stage. We utilize a visualization cell to explore oil-recovery mechanisms under representative reservoir conditions. We soak oil-saturated core plugs with methane at 4,150 psig and a reservoir temperature of 90°C to restore initial reservoir conditions. After equilibrium, we deplete the cell pressure at a controlled rate to simulate the primary production stage. Using two shale samples with different thermal maturity levels, our results demonstrate that methane diffuses into both cores during the soaking; however, it dissolves in oil only in the mature shale sample, resulting in a live oil with a solution gas-oil ratio of 932 standard ft3/stock tank barrel. During the primary production stage, we observe significant oil production under the solution-gas drive mechanism from the mature shale, while the immature shale exhibits negligible oil production. Natural fractures enhance gas penetration into the core, contributing to increased oil production in the primary production stage. Ultimately, the mature shale sample exhibits an oil recovery factor of 25.6% of original oil-in-place after the primary production stage, a remarkable contrast to 1.5% recovery observed in the immature shale. This difference is attributed to the immaturity of the organic matter, insufficient original oil-in-place, and absence of connected oil-wet pore network in the immature shale sample, confirmed by wettability evaluation and rock-eval pyrolysis data.","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"110 8","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395158","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":"Minimizing Fugitive Emissions in Post Fracturing Sand Separation Using A Vortex Separator","authors":"C. Johnston, A. Natarajan","doi":"10.2118/218037-ms","DOIUrl":"https://doi.org/10.2118/218037-ms","url":null,"abstract":"\u0000 The drill-out, clean-up, and testing of a hydraulically fractured well is critical to ensure stimulation success. This period is important both for production and environmental reasons, due to the high risk of gas release. Most wells require a sand separator during clean-up, which are a source of fugitive emissions. These emissions often go unreported during flowback due to the challenge in their quantification.\u0000 This work improves on a study by Wasfy et al (SPE, 2019) which investigated sand separator fugitive emissions. The analysis is improved by categorizing the differences in draining mechanisms between four different separator styles: vertical cyclonic separators, horizontal separators, spherical separators, and vortex separators. A simple 3-stage mathematical model is presented to calculate emissions based on drain duration for online sand separators which are drained without isolating the vessel. A vortex separator was found to provide the lowest overall fugitive emissions release. Prior work was found to have significantly underestimated the emissions released by horizontal separators.\u0000 Field experiments were performed using freestanding atmospheric gas plume sensors to validate the model. Measured gas releases were within 6% of the volume predicted by the 3-stage model at field conditions. This model can be used by engineers to accurately assess different styles of sand separators in hydraulic fracturing, allowing for more accurate reporting and quantification of fugitive emissions.","PeriodicalId":517523,"journal":{"name":"Day 1 Wed, March 13, 2024","volume":"94 11","pages":""},"PeriodicalIF":0.0,"publicationDate":"2024-03-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"140395511","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}