SPE Production & Operations最新文献

{"title":"Production Profiles Recorded Using Fiber-Optic Technology in Wells with Electrical Submersible Pump Lift System","authors":"Gabriel Jaime Ramirez Palacio, F. Almario, Alexander Castro Chacon, Eliana Meza Rojas, Nini Johana Hernandez, Maria Valencia","doi":"10.2118/215848-pa","DOIUrl":"https://doi.org/10.2118/215848-pa","url":null,"abstract":"\u0000 Fiber-optic distributed sensor technology has rapidly evolved over the past 30 years, becoming very useful in the hydrocarbon sector for different operations, such as pipeline leak monitoring, production and injection logging, fracture monitoring, vertical seismic profiling, and steam injection, among others. Monitoring temperature is a critical aspect of reservoir development and a well’s life cycle, given its broad range of applications. Temperature profiling is commonly used in production logging, often in conjunction with other sensors to quantify and identify fluids. This paper discusses two prevalent scenarios encountered in the Llanos Orientales region of Colombia, where 28 wells with electrical submersible pump (ESP) lifting systems were impacted. During the execution of these fiber-optic logs, two conditions of particular interest were explored: wells with low-flow rates below 500 barrels per day and wells with mechanical limitations that preclude monitoring with conventional sensors due to the presence of stainless-steel bands at the bottom of the well. The fiber-optic string provided access to the drilling zone, enabling temperature and pressure monitoring of the production intervals. To interpret the data, a probabilistic model based on enthalpy balance, mass, and conservation of momentum was used to determine the well’s production profile.","PeriodicalId":153181,"journal":{"name":"SPE Production & Operations","volume":"44 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115579040","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 Methods for Top-Down Methane Emission Measurements of Oil and Gas Facilities in an Offshore Environment Using a Miniature Methane Spectrometer and Long-Endurance Uncrewed Aerial System","authors":"Brendan Smith, Stuart Buckingham, Daniel F. Touzel, A. Corbett, Charles Tavner","doi":"10.2118/206181-pa","DOIUrl":"https://doi.org/10.2118/206181-pa","url":null,"abstract":"\u0000 With atmospheric methane concentrations rising and spurring increased social concern, there is a renewed focus in the oil and gas industry on methane emission monitoring and control. In 2019, a methane emission survey at a bp asset west of Shetland was conducted using a closed-cavity methane spectrometer mounted onboard a long-endurance fixed-wing uncrewed aerial vehicle (UAV). This flight represents the first methane emissions survey of an offshore facility with a miniature methane spectrometer onboard a UAV with subsequent flights performed. A small laser spectrometer was modified from an open-cavity system to a closed-cavity onboard the aircraft and yielded in-flight detection limits (3 seconds) of 1,065 ppb methane above background for the 2019/2020 sensor version and 150 ppb for the 2021 sensor versions. Through simulation, the minimum detection limits of sensors in mass flow rate were determined to be 50 kg/h for the 2019/2020 campaign and 2.5 kg/h for the 2021 campaigns, translating to an obtainable measurement for 23% and 82% of assets reporting higher than 1 kg/h according to the 2019 Environmental Emissions Monitoring System (EEMS) data set, respectively. To operationalize the approach, a simulation tool for flight planning was developed using a Gaussian plume model and a scaled coefficient of variation to invoke expected methane concentration fluctuations at short time intervals. Two methods were developed to calculate offshore facility-level emission rates from the geolocated methane concentration data acquired during the emission surveys. Furthermore, a Gaussian plume simulator was developed to predict plume behavior and aid in error analysis. These methods are under evaluation, but all allow for the rapid processing (<24 hours) of results upon landing the aircraft. Additional flights were conducted in 2020 and 2021 with bp and several UK North Sea operators through a Net Zero Technology Centre (NZTC)-funded project, resulting in a total of 18 methane emission survey flights to 11 offshore assets between 2019 and 2021. The 2019 flight, and subsequent 2020–2021 flights, demonstrated the potential of the technology to derive facility-level emission rates to verify industry emission performance and data.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"106 6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131361911","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":"Study on the Synthesis and Properties of a New Salt-Resistant Drag Reducer","authors":"X. Ying, Z. Lang, Chen Pengfei","doi":"10.2118/215849-pa","DOIUrl":"https://doi.org/10.2118/215849-pa","url":null,"abstract":"\u0000 To solve the problem of poor salt resistance of conventional drag reducers, a hydrophobic associative polymer drag reducer was prepared by inverse emulsion polymerization with acrylamide (AM), methacrylic acid (MAA), 2-acrylamide-2-methylpropane sulfonic acid (AMPS), and hexadecyl dimethyl allyl ammonium chloride (C16DMAAC) as the main monomers. The synthetic product was confirmed as the target product by infrared (IR), nuclear magnetic resonance (NMR), and mass spectrometry (MS). The viscosity-average molecular weight of the prepared drag reducer is 1100×104 g/mol. The pipeline friction results show that the drag reducer has good friction reduction and salt resistance. When the concentration in clean water is 0.06%, the maximum friction reduction rate is 71.1%. When the salinity is 5×104 mg/L, the calcium ion concentration is 2000 mg/L, and the suspended solid content is 500 mg/L, the maximum friction reduction rate is 68.9% when the concentration of the drag reducer is 0.06%. Salt water will not significantly lower the friction reduction rate. If the concentration of the drag reducer is increased to 0.08%, the maximum drag reduction rate will reach 73.8%. The microrheological test results of the friction reducer solution show that, at 0.2% concentration, there is no network structure between friction reducer molecules, which is consistent with Newtonian fluids possessing a certain viscosity. The elasticity index (EI) of the drag reducer solution is basically unchanged over time, maintaining good friction reduction and sand-carrying performance during the shearing process of large displacement pumping.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"55 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116947622","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":"New Hybrid MCDM Approach for an Optimal Selection of Maintenance Strategies: Results of a Case Study","authors":"N. E. H. Khanfri, N. Ouazraoui, A. Simohammed, I. Sellami","doi":"10.2118/215846-pa","DOIUrl":"https://doi.org/10.2118/215846-pa","url":null,"abstract":"\u0000 Industrial systems are becoming more sophisticated, and their failure can result in significant losses for the company in terms of production loss, maintenance costs, fines, image loss, etc. Conventional approaches to modeling and evaluating the failure mechanisms of these systems do not consider certain important aspects, such as the interdependencies between failure modes (FMs) with information and data containing uncertainties as they are generally collected from experts’ judgments. These restrictions may lead to improper decision-making. The use of more advanced techniques to model and assess the interdependencies among components’ failures under uncertainties seems to be more than necessary to overcome these deficiencies.\u0000 It is in this context that the proposed approach fits. It consists of proposing a hybrid multicriteria decision-aking (MCDM) approach that combines several techniques for a better selection of maintenance strategies. Using the failure mode and effects analysis (FMEA) technique, the potential FMs of components, along with their causes and effects, are identified. The relative importance (or weight) of these FMs is determined using the fuzzy simple additive weighing (FSAW) method based on how they affect the system’s goals. The causal relationships between FMs and their final weights are determined by the fuzzy cognitive maps (FCM) method and the nonlinear Hebbian learning and differential evolution (NHL-DE) algorithm. Finally, based on the final FM weights provided by the FCM, the simple additive weighing (SAW) method is used to select the optimal maintenance strategies. The results of applying the proposed approach to an operating compressor lubrication and sealing oil system demonstrate its importance and usefulness in assisting system operators to efficiently allocate the optimal maintenance strategies, considering the strong correlation between FMs and their effects on system performance while accounting for the uncertainties associated with experts’ judgments. These correlation effects have led to changes in the assigned weights of the selected FMs. Specifically, the FM related to the low output of the lube/seal oil pump, which was initially assigned a lower priority, and with the correlation effects has become the first critical FM. This shift in prioritization emphasizes the need to address this particular FM promptly. By focusing on addressing these high-priority FMs, maintenance efforts can be optimized to prevent or mitigate more severe consequences. Among the various maintenance strategies evaluated, it was determined that the combination of condition-based maintenance (CBM) and precision maintenance (PrM) yields the most favorable outcome in terms of mitigating the impact of accidental failures and undesired events on the selected system.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"648 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116419873","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":"Autonomous Inflow Control Valve for Medium-Light Oil and Its Effective Performance","authors":"K. Langaas, E. Gisholt, A. Bjerke, V. Mathiesen","doi":"10.2118/214342-pa","DOIUrl":"https://doi.org/10.2118/214342-pa","url":null,"abstract":"\u0000 Many horizontal oil wells will after a time start producing unwanted fluids. Autonomous inflow control valves may help to choke these unwanted fluids and consequently improve carbon efficiency. This paper publishes new experimental data describing how an autonomous inflow control valve manages medium-light oil (6 cp), water, and gas at reservoir conditions. A further objective is to evaluate how this valve might impact well performance under various conditions.\u0000 To verify the single- and multiphase flow behavior of the valve, extensive flow loop experiments were performed. Initial testing was done in a model fluid laboratory, while a more extensive test was performed at reservoir conditions (i.e., with formation water, reservoir oil, and hydrocarbon gas at the given reservoir temperature and pressure). To explore and understand the impact of this valve for various reservoir scenarios, a simple conceptual reservoir model with realistic boundary conditions was used.\u0000 At various differential pressures, the single-phase oil, water, and gas rates were measured. Performance at varying water and gas fractions was measured to get an improved understanding and knowledge of multiphase flow occurring in a well. The results show clearly that the valve will choke gas and water effectively, both at single-phase and multiphase flow conditions. The reservoir and model fluid evaluations show consistent results. The valve shows roughly a monotonic decreasing total rate with decreasing oil fraction, implying that the valve will always prioritize sections with the largest oil fraction. A mathematical model match of the valve performance is possible via the 10-parameter extended autonomous inflow control device (AICD) equation that enables practical evaluation of the valve in industry-standard reservoir simulators. Various scenarios are explored with a conceptual reservoir model, and the autonomous inflow control valve shows its capacity to reduce water production and enable a more gradual and controlled increase in gas/oil ratio for most scenarios. The autonomous inflow control valve shows its largest potential to reduce unwanted fluids and increase oil recovery when used in segmented reservoirs. In cases with uncertain aquifer and/or gas cap strength, or large variation in effective permeability, the valve will make an infill well more robust as it autonomously adapts to reality, chokes unwanted fluids, and consequently enables more carbon-efficient reservoir management.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125982378","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":"Challenges and Practices for Recovering Stuck Coiled Tubing Pipe","authors":"S. Hassig Fonseca, R. Torres, Z. Liu, F. Jahn, G. Tagarot, S. Baca, H. Guevara, J. Botan, C. Villacres, J. Boas","doi":"10.2118/215819-pa","DOIUrl":"https://doi.org/10.2118/215819-pa","url":null,"abstract":"\u0000 Stuck coiled tubing (CT) is a main operational risk leading to delays, deferred production, or even the loss of a well. Despite general commonalities, each CT recovery can face unique challenges, including managing high pressure, working under limited spatial or lifting constraints, establishing well control, or handling a cable inside the CT.\u0000 This study consolidates learnings and proposes a general workflow for a basic stuck pipe scenario, rig up, recovery pressure control equipment (RPCE) and well control, CT free point evaluation, bottomhole assemblies (BHAs) and workflows for cutting and freeing the CT pipe downhole, and recovery of the CT at the surface. A consolidation of published case studies provides specific examples of the hardware, workflows, and operational considerations. In addition, the presentation of a recent case study extends the discussion to the challenges introduced by the presence of a cable in the stuck CT and its respective solution.\u0000 The case study reviews the planning and execution of a CT recovery, including the use of decision trees to guide the decision-making process. It details fit-for-purpose hardware for safely anchoring the cable; packoffs for accessing, tensioning, and recovering it with slickline (SLK); an opening for deploying the wireline (WL) cutting BHA; and valves for pressure testing and well control. That workflow successfully freed 6,818 ft of stuck CT and allowed recovery of the pipe without a workover rig on location, eliminating 11 days of rig time during subsequent tubing pulling. This is the first such documented recovery case worldwide based on a thorough literature review.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117087428","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 Design and Numerical Simulation Research of Downhole Electrical Heaters for In-Situ Oil Shale Exploitation","authors":"Tengfei Sun, Hao Liu, Tingjun Yan, Yang Zhang, Baokang Wu, Ziyang Liu, Zhilei Wang, Yacong Fan, Yongan Li, Yongliang Han","doi":"10.2118/215817-pa","DOIUrl":"https://doi.org/10.2118/215817-pa","url":null,"abstract":"\u0000 To improve the overall performance of continuous spiral baffle heating systems, we propose in this paper two different structural models of electric heaters for in-situ shale oil wells. The models are simulated using Fluent software to investigate the flow and heat-transfer characteristics under different mass flow rates. The variation in heat-transfer coefficient, pressure drop, and overall performance of the heating plate under different gas mass flow rates and heights of heating and shielding plates are analyzed. The performance of the two different heater structures is compared with Wang’s laboratory experiment. The results show that Model I of the heating system has the best overall performance when the gas mass flow rate is between 9.74×10−3 kg/s and 1.624×10−2 kg/s, and the height of the heating and shielding plates is 35 mm at a mass flow rate of 9.74×10–3 kg/s. Wang’s pressure drop (ΔP) is more than 2.48 times higher than that of Model I and more than 6.49 times higher than that of Model II, while the heat-transfer coefficient (h) of both Model I and Model II is increased by more than 15% compared to Wang’s experiment. The overall performance (g) of Model II is increased by more than 5.7 times compared to Wang’s experiment, and the overall performance (g) of Model II is increased by more than 1.68 times compared to Model I. These results provide a theoretical basis for optimizing the design of continuous spiral baffle heating systems.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129295038","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":"Computational Fluid Dynamics Simulation of Oil-Water Batch Transport in a Pumpless Virtual Flow Loop","authors":"Lei Xie, G. Mao, Kai Wang, Zhiping Li","doi":"10.2118/215840-pa","DOIUrl":"https://doi.org/10.2118/215840-pa","url":null,"abstract":"\u0000 Batch transportation of oil and water is a new transportation method in oil and gas gathering and transportation pipelines. Its corrosion inhibition effect has been preliminarily verified in a horizontal pipe experiment. However, achieving overall visualization in traditional loops is difficult, resulting in limited flow pattern classification and analysis of influencing factors. Combining the advantages of the traditional flow loop and the wheel flow loop, we introduce in this paper a round-head straight pipe loop and analyze the influence of key factors on the evolution of the flow pattern of the oil-water interface and the dimensionless length of the oil-water film (L~o, L~w) on the pipe wall through computational fluid dynamics (CFD) numerical simulation. The results show that the batch transportation of oil and water using the round-head straight pipe loop is more in line with the flow characteristics of oil and water two-phase flow in gathering pipelines. Three distinct three-layered flow patterns were identified, which are Flow Pattern I (oil-in-water in the upper layer, annular flow in the middle layer, and oil as the annular phase, water as the core phase, and oil-in-water in the lower layer, abbreviated as DW/O-AN-DW/O), Flow Pattern II (oil phase in the upper layer, annular flow in the middle layer, water as the annular phase, oil as the core phase, and oil in the lower layer, abbreviated as O-AN-O), and Flow Pattern III (oil phase in the upper layer, water-in-oil dispersion flow in the middle layer, and oil in the lower layer, abbreviated as O-DO/W-O). Additionally, parametric analysis reveals that the velocity of the rigid body (ν) has the greatest influence on the coverage rate of the oil film on the pipe wall, followed by the viscosity of crude oil. The density of crude oil has the least influence. The round-head straight pipe loop model offers an accurate simulation of the process of oil and water batch transportation in actual production pipelines. Therefore, the corrosion mitigation efficiency increases with the increase in oil viscosity when the viscosity of the oil lies within the range of 0.01–1 Pa·s. This increase is due to the formation of a more stable oil film on the pipe wall at higher viscosities. When the speed of the rigid body ranges from 0.5 to 1 m/s, due to the small fluid velocity, the erosion effect on the oil film on the pipe wall is relatively small, and the corrosion mitigation efficiency remains stable within a wide range.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"96 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127490679","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":"Poroelastic-Flow Model for Permeability Loss Management in Biot’s Stress-Sensitive Oil Reservoirs with Finite Extent Hydraulic Fractures During Well-Reservoir Drawdown","authors":"F. Fernandes, A. Braga","doi":"10.2118/215809-pa","DOIUrl":"https://doi.org/10.2118/215809-pa","url":null,"abstract":"\u0000 The evaluation of geomechanical effects and fluid flow related to pressure transient phenomena in fractured Biot’s stress-sensitive oil reservoirs is essential to minimize the mechanical formation damage and extend the well-reservoir life cycle for economical production. Therefore, the management of the damage caused by effective permeability loss in this type of reservoir becomes essential to productivity maintenance. This paper proposes a new unsteady-state poroelastic solution for the nonlinear hydraulic diffusivity equation (NHDE) in Biot’s effective stress-sensitive reservoirs fully penetrated by fractured oil wells. The hydraulic fracture in the proposed mathematical modeling is finite with tip effects and crosses the whole reservoir net-pay. A new permeability stress-sensitive pseudopressure m⁢(σ′) is developed, and the solution of the NHDE is derived in terms of this function. The NHDE is expanded in a first-order asymptotic series, and a poroelastic integro-differential solution coupled to a Green’s function is used to represent the source/sink term. A set of pore pressure and permeability data is used from geomechanical literature and transformed into effective stress through Biot’s equation. The effects of the Biot’s coefficient, overburden stress, oil flow rate, fracture’s tip, and proppant porosity arrangements are simulated. The results show that these parameters are essential to minimize formation damage. Model calibration is performed using a numerical oil flow simulator named IMEX®, widely used in the oil industry. The accuracy, ease of implementation, and low computational costs constitute the main advantages of the model addressed in this paper. Hence, it may be a valuable and attractive mathematical tool to identify flow regimes, providing permeability loss control and supporting well-reservoir management.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"30 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121859403","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":"Empirical Correlations for Predicting Flow Rates Using Distributed Acoustic Sensor Measurements, Validated with Wellbore and Flow Loop Data Sets","authors":"Jagadeeshwar Tabjula, Rishikesh Shetty, T. Adeyemi, Jyotsna Sharma","doi":"10.2118/215834-pa","DOIUrl":"https://doi.org/10.2118/215834-pa","url":null,"abstract":"\u0000 Distributed acoustic sensing (DAS) is an emerging surveillance technology that is becoming increasingly popular in the oil and gas industry for real-time flow monitoring. However, there are limited studies that rigorously quantify flow rates using DAS. This work expands the existing literature by presenting a detailed workflow for accurately estimating fluid flow rates from DAS data using time- and frequency-domain signal processing. Three simple empirical correlation functions (linear, exponential, and cubic) are developed and tested to predict flow rates from DAS. The proposed correlations are demonstrated for flow rates ranging from 50 to 300 gallons per minute (GPM) in a vertical 5,163-ft-deep wellbore and from 12 to 36 GPM in a horizontal surface flow loop. Tests were performed using a single-phase flow of water as well as using synthetic oil-based drilling mud. Time-domain DAS processing using root-mean-square (RMS) value and frequency-domain processing using frequency band energy (FBE) is evaluated, followed by a statistical approach to minimize the influence of outliers. The RMS and FBE approaches are individually compared for flow prediction, and the performance of the correlations is rigorously evaluated on a blind data set that was not originally used for developing the correlations. For both the wellbore and flow loop data sets, a coefficient of determination (or R2) greater than 0.95 with an average flow rate prediction error of less than 10% was achieved for the best-performing correlation for the blind test data. The analysis procedure and workflow presented in this study can be adopted and extended to different operating conditions for quantitative flow rate prediction using DAS.","PeriodicalId":153181,"journal":{"name":"SPE Production &amp; Operations","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2023-06-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123726100","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}