Models for jet pumps currently are derived under the assumption that the power and well fluids are incompressible liquids that, in many cases, are assumed to have equal densities: When either the well or the power fluid contains gas, current design practices still use the equations for incompressible liquids and account for the presence of gas by modifying the mass-flow-rate ratio and the friction-loss coefficients. This paper proposes a new approach to modeling pumps operating under multiphase-flow conditions.
{"title":"Modeling and Design of jet pumps","authors":"Dimitri Hatziavramidis","doi":"10.2118/19713-PA","DOIUrl":"https://doi.org/10.2118/19713-PA","url":null,"abstract":"Models for jet pumps currently are derived under the assumption that the power and well fluids are incompressible liquids that, in many cases, are assumed to have equal densities: When either the well or the power fluid contains gas, current design practices still use the equations for incompressible liquids and account for the presence of gas by modifying the mass-flow-rate ratio and the friction-loss coefficients. This paper proposes a new approach to modeling pumps operating under multiphase-flow conditions.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"49 1","pages":"413-419"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82247046","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}
In this paper, a simple model suitable for hand calculations is presented to predict temperature profiles in two-phase flowing wells. The model, developed with measured temperature data from 392 wells, assumes that the heat transfer within the wellbore is steady-state. Comparisons between the model's predictions and field data indicate that the model is highly accurate within its range of application.
{"title":"Predicting temperature profiles in a flowing well","authors":"R. Sagar, D. Doty, Z. Schmidt","doi":"10.2118/19702-PA","DOIUrl":"https://doi.org/10.2118/19702-PA","url":null,"abstract":"In this paper, a simple model suitable for hand calculations is presented to predict temperature profiles in two-phase flowing wells. The model, developed with measured temperature data from 392 wells, assumes that the heat transfer within the wellbore is steady-state. Comparisons between the model's predictions and field data indicate that the model is highly accurate within its range of application.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"238 1","pages":"441-448"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79641967","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}
Cooling of rock by water injection frequently causes fracturing of wells. This paper describes a 3D simulation model of thermally induced fracturing. It is used to show that fractures often tend to grow vertically into permeable zones. Procedures are outlined for confining fracture growth in wells where it will assist waterflood sweep performance.
{"title":"Modeling the vertical confinement of injection-well thermal fractures","authors":"P. Clifford, P. J. Berry, H. Gu","doi":"10.2118/20741-PA","DOIUrl":"https://doi.org/10.2118/20741-PA","url":null,"abstract":"Cooling of rock by water injection frequently causes fracturing of wells. This paper describes a 3D simulation model of thermally induced fracturing. It is used to show that fractures often tend to grow vertically into permeable zones. Procedures are outlined for confining fracture growth in wells where it will assist waterflood sweep performance.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"1 1","pages":"377-383"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84581836","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}
This paper presents a software technique for measuring individual phase flow rates in two-phase flow. The technique is based on the extraction, classification, and identification of stochastic features from turbulent pressure and void-fraction waveforms. Experiments in a horizontal air/water loop showed that a set of stochastic features is uniquely related to the individual phase flow rates. The software flowmeter is calibrated in situ by compilation of feature sets related to individual phase flow rates in a data base. On-line flow-rate measurement is made by a pattern recognition technique that identifies the best match to the measured feature vector from the calibration data base.
{"title":"A Software Technique for Flow-Rate Measurement in Horizontal Two-Phase Flow","authors":"T. Darwich, H. Toral, J. Archer","doi":"10.2118/19510-PA","DOIUrl":"https://doi.org/10.2118/19510-PA","url":null,"abstract":"This paper presents a software technique for measuring individual phase flow rates in two-phase flow. The technique is based on the extraction, classification, and identification of stochastic features from turbulent pressure and void-fraction waveforms. Experiments in a horizontal air/water loop showed that a set of stochastic features is uniquely related to the individual phase flow rates. The software flowmeter is calibrated in situ by compilation of feature sets related to individual phase flow rates in a data base. On-line flow-rate measurement is made by a pattern recognition technique that identifies the best match to the measured feature vector from the calibration data base.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"152 1","pages":"265-270"},"PeriodicalIF":0.0,"publicationDate":"1991-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79607496","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}
R. Kane, S. M. Wilheim, Toshio Yoshida, Matsui Shigetomo, T. Iwase
This paper presents the results of laboratory investigations conducted to better our definition of the serviceability of bimetallic pipe manufactured by the thermohydraulic (tight-fit) method for Mobile Bay service. Both Alloy 625/API X-65 and Alloy 825/API X-65 tight-fit pipe (TFP) were evaluated under conditions of standard corrosion test environments to evaluate the metallurigical conditions fo the corrosion-resistant-alloy (CRA) liner tubes, long-term, full-scale TFP exposure under a simulated Mobile Bay production environment containing high levels of H{sub 2}S and CO{sub 2}, and hydrogen-permeation experiments designed to examine potential effects of CRA liner collapse from hydrogen produced by corrosion on the ID and/or cathodic protection on the OD. Results indicate that bimetallic TFP exhibited an acceptable metallurgical condition of the CRA liner materials. Under the simulated Mobile Bay production environment, TFP exhibited good resistance to general corrosion, stress-corrosion cracking (SCC), and liner collapse. Hydrogen-permeation tests indicate that very conservative estimates of service-life liner collapse from interfacial hydrogen pressure range from 150 to more than 800 years, depending on conditions. For all practical purposes, liner collapse from hydrogen is not a limiting factor for TFP flowline applications.
{"title":"Analysis of Bimetallic Pipe for Sour Service","authors":"R. Kane, S. M. Wilheim, Toshio Yoshida, Matsui Shigetomo, T. Iwase","doi":"10.2118/20837-PA","DOIUrl":"https://doi.org/10.2118/20837-PA","url":null,"abstract":"This paper presents the results of laboratory investigations conducted to better our definition of the serviceability of bimetallic pipe manufactured by the thermohydraulic (tight-fit) method for Mobile Bay service. Both Alloy 625/API X-65 and Alloy 825/API X-65 tight-fit pipe (TFP) were evaluated under conditions of standard corrosion test environments to evaluate the metallurigical conditions fo the corrosion-resistant-alloy (CRA) liner tubes, long-term, full-scale TFP exposure under a simulated Mobile Bay production environment containing high levels of H{sub 2}S and CO{sub 2}, and hydrogen-permeation experiments designed to examine potential effects of CRA liner collapse from hydrogen produced by corrosion on the ID and/or cathodic protection on the OD. Results indicate that bimetallic TFP exhibited an acceptable metallurgical condition of the CRA liner materials. Under the simulated Mobile Bay production environment, TFP exhibited good resistance to general corrosion, stress-corrosion cracking (SCC), and liner collapse. Hydrogen-permeation tests indicate that very conservative estimates of service-life liner collapse from interfacial hydrogen pressure range from 150 to more than 800 years, depending on conditions. For all practical purposes, liner collapse from hydrogen is not a limiting factor for TFP flowline applications.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"39 1","pages":"291-296"},"PeriodicalIF":0.0,"publicationDate":"1991-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84617893","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}
This paper introduces the concept of characteristic time as a measure to separate and to optimize the roles of Griffith surface energy and fracture-fluid dissipation energy during hydraulic fracture evolutions. The analysis reveals two separate sets of solutions that correspond to two distinct time regimes of hydraulic fracture propagation: a dominant fluid dissipation energy and a dominant fracture surface energy regime. Each influence domain is governed by a characteristic time and demarcated by a transition region, where the energy contributions of each are of the same order of magnitude. Verification of the theoretical response trends and the use of the characteristic-time concept as a design tool are also presented.
{"title":"Characteristic-Time Concept in Hydraulic Fracture Configuration Evolution and Optimization (includes associated papers 23551 and 23552 )","authors":"T. Lee, S. Advani, J. M. Avasthi","doi":"10.2118/19000-PA","DOIUrl":"https://doi.org/10.2118/19000-PA","url":null,"abstract":"This paper introduces the concept of characteristic time as a measure to separate and to optimize the roles of Griffith surface energy and fracture-fluid dissipation energy during hydraulic fracture evolutions. The analysis reveals two separate sets of solutions that correspond to two distinct time regimes of hydraulic fracture propagation: a dominant fluid dissipation energy and a dominant fracture surface energy regime. Each influence domain is governed by a characteristic time and demarcated by a transition region, where the energy contributions of each are of the same order of magnitude. Verification of the theoretical response trends and the use of the characteristic-time concept as a design tool are also presented.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"46 1","pages":"323-330"},"PeriodicalIF":0.0,"publicationDate":"1991-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82496153","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}
This paper discusses the theories of repair sealants on ball valves and testing done on various sealants to determine their basic characteristics. Preliminary penetration, chemical, and flow testing results are presented, along with a discussion of field problems.
{"title":"Theory, history, and results of sealants for subsea service","authors":"R. Pennell, B. Baugh","doi":"10.2118/20857-PA","DOIUrl":"https://doi.org/10.2118/20857-PA","url":null,"abstract":"This paper discusses the theories of repair sealants on ball valves and testing done on various sealants to determine their basic characteristics. Preliminary penetration, chemical, and flow testing results are presented, along with a discussion of field problems.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"26 1","pages":"277-282"},"PeriodicalIF":0.0,"publicationDate":"1991-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78235673","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
{"title":"Selection and Application of BaSO4 Scale Inhibitors for a CO2 Flood, Rangely Weber Sand Unit, Colorado","authors":"P. Shuler, E. A. Freitas, K. Bowker","doi":"10.2118/18973-PA","DOIUrl":"https://doi.org/10.2118/18973-PA","url":null,"abstract":"","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"27 1","pages":"259-264"},"PeriodicalIF":0.0,"publicationDate":"1991-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88628584","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}
The most popular clay stabilizers used recently in well-treating solutions are classified as cationic organic polymers (COP's). This paper reports on studies that have shown these stabilizers to be ineffective in microdarcy to low-millidarcy sandstones. Recent research led to the development of a stabilizer applicable to formations with permeabilities of 0.010 md and higher that also provides enhanced load-water recovery and more efficient placement from gelled-water solutions.
{"title":"Clay Stabilization in Low-Permeability Formations","authors":"R. Himes, E. Vinson, D. E. Simon","doi":"10.2118/18881-PA","DOIUrl":"https://doi.org/10.2118/18881-PA","url":null,"abstract":"The most popular clay stabilizers used recently in well-treating solutions are classified as cationic organic polymers (COP's). This paper reports on studies that have shown these stabilizers to be ineffective in microdarcy to low-millidarcy sandstones. Recent research led to the development of a stabilizer applicable to formations with permeabilities of 0.010 md and higher that also provides enhanced load-water recovery and more efficient placement from gelled-water solutions.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"94 1","pages":"252-258"},"PeriodicalIF":0.0,"publicationDate":"1991-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74974887","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}
This paper reports on the Tensleep formation in the Lost Soldier field that has been pattern waterflooded since 1976. Injection wells have historically exhibited large declines in injectivity and required frequent workovers. Because those declines were originally attributed to near-well damage from poor injection-water quality, a cleanup program was initiated that significantly reduced the amount and size of suspended particles in the injection water. Despite these improvements, injectivity continued to decline in many wells. Subsequent analyses of well histories, pressure-falloff tests, and reservoir petrophysical properties suggest that the reservoir damage in many instances was not only a sandface phenomenon, but also a result of deep particle invasion. Workover procedures were altered to treat the formation beyond the near-wellbore area, resulting in increased injectivities compared with the historical norm.
{"title":"Formation Damage From Fine Particulate Invasion: An Example From the Lost Soldier Tensleep Formation","authors":"R. Rickford, T. Finney","doi":"10.2118/18886-PA","DOIUrl":"https://doi.org/10.2118/18886-PA","url":null,"abstract":"This paper reports on the Tensleep formation in the Lost Soldier field that has been pattern waterflooded since 1976. Injection wells have historically exhibited large declines in injectivity and required frequent workovers. Because those declines were originally attributed to near-well damage from poor injection-water quality, a cleanup program was initiated that significantly reduced the amount and size of suspended particles in the injection water. Despite these improvements, injectivity continued to decline in many wells. Subsequent analyses of well histories, pressure-falloff tests, and reservoir petrophysical properties suggest that the reservoir damage in many instances was not only a sandface phenomenon, but also a result of deep particle invasion. Workover procedures were altered to treat the formation beyond the near-wellbore area, resulting in increased injectivities compared with the historical norm.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"27 1","pages":"247-251"},"PeriodicalIF":0.0,"publicationDate":"1991-08-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81341377","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}
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