This paper describes the impact that thermally induced fracturing (TIF) has had on the North Sea Ula field injection wells, allowing higher than anticipated water injection rates to be achieved. This work also discusses how thermal stress reduced fracture propagation pressures by 2,000 psi and how a 3D simulation code developed to model TIF was used. Injection-water-quality specifications and techniques to optimize TIF are presented.
{"title":"Thermally Induced Fracturing of Ula Water Injectors","authors":"A. Svendson, Wright, P. Clifford, P. J. Berry","doi":"10.2118/20898-PA","DOIUrl":"https://doi.org/10.2118/20898-PA","url":null,"abstract":"This paper describes the impact that thermally induced fracturing (TIF) has had on the North Sea Ula field injection wells, allowing higher than anticipated water injection rates to be achieved. This work also discusses how thermal stress reduced fracture propagation pressures by 2,000 psi and how a 3D simulation code developed to model TIF was used. Injection-water-quality specifications and techniques to optimize TIF are presented.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"9 1","pages":"384-390"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90195972","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}
Development of simultaneous downhole flow-rate/pressure measurement equipment has permitted better determination of reservoir properties. Application of such equipment to layered reservoirs allows determination of individual layer properties. This paper reviews state-of-the-art pressure and flow-rate devices, discusses the advantages and limitations of specific equipment, and addresses the need to evaluate current tools and areas for future research.
{"title":"State-of-the-art simultaneous downhole flow-rate and pressure measurement equipment","authors":"G. W. Haws, B. L. Knight","doi":"10.2118/20595-PA","DOIUrl":"https://doi.org/10.2118/20595-PA","url":null,"abstract":"Development of simultaneous downhole flow-rate/pressure measurement equipment has permitted better determination of reservoir properties. Application of such equipment to layered reservoirs allows determination of individual layer properties. This paper reviews state-of-the-art pressure and flow-rate devices, discusses the advantages and limitations of specific equipment, and addresses the need to evaluate current tools and areas for future research.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"5 1","pages":"427-434"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78522352","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 provides a method of extending the concept of dimensionless fracture conductivity to the design of fracture conductivity in wells to be produced at rates that cause non-Darcy flow down the fracture. Such flow rates are common in gas wells and occasionally occur in oil wells. the correction requires knowledge of the expected producing rate and calculation of a Reynolds number characterizing flow in the fracture near the wellbore.
{"title":"A Method for Correcting Dimensionless Fracture Conductivity for Non-Darcy Flow Effects","authors":"J. Gidley","doi":"10.2118/20710-PA","DOIUrl":"https://doi.org/10.2118/20710-PA","url":null,"abstract":"This paper provides a method of extending the concept of dimensionless fracture conductivity to the design of fracture conductivity in wells to be produced at rates that cause non-Darcy flow down the fracture. Such flow rates are common in gas wells and occasionally occur in oil wells. the correction requires knowledge of the expected producing rate and calculation of a Reynolds number characterizing flow in the fracture near the wellbore.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"23 1","pages":"391-394"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78709709","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 mechanistic model is developed for the prediction of annular two-phase flow behavior in gas wells. The model can predict annular flow characteristics, such as liquid film thickness, gas void fraction, and pressure gradient. It was evaluated against a data bank of 75 wells for which the pressure drop between the bottom of the well and the wellhead was available. The model was also compared with data from two wells with measured pressure profiles. Model predictions are in agreement with these data and superior to most commonly used correlations.
{"title":"Modeling Annular Flow Behavior for Gas Wells","authors":"Í. M. Alves, E. Caetano, K. Minami, O. Shoham","doi":"10.2118/20384-PA","DOIUrl":"https://doi.org/10.2118/20384-PA","url":null,"abstract":"In this paper a mechanistic model is developed for the prediction of annular two-phase flow behavior in gas wells. The model can predict annular flow characteristics, such as liquid film thickness, gas void fraction, and pressure gradient. It was evaluated against a data bank of 75 wells for which the pressure drop between the bottom of the well and the wellhead was available. The model was also compared with data from two wells with measured pressure profiles. Model predictions are in agreement with these data and superior to most commonly used correlations.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"4 1","pages":"435-440"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88641694","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}
Nickel-based, corrosion-resistant alloys (CRA's) were subjected to extensive corrosion testing and evaluation for potential use in hot, deep, sour wells. The Ni-Cr-Mo-W system was used in sour-gas wells in south Mississippi, Wyoming, and Mobile Bay. Corrosion data, mechanical properties, and resistance to environmental stress cracking are described for several oil country tubular goods (OCTG). Better understanding of metallurgical factors and of the role of alloying for enhanced resistance to corrosion, along with advanced in materials processing, are reviewed in terms of their impact on OCTG product reliability, improved safety, and cost-effectiveness
{"title":"Corrosion-resistant alloys for hot, deep, sour wells; Properties and experience","authors":"A. Asphahani, J. C. Prouheze, G. Petersen","doi":"10.2118/19184-PA","DOIUrl":"https://doi.org/10.2118/19184-PA","url":null,"abstract":"Nickel-based, corrosion-resistant alloys (CRA's) were subjected to extensive corrosion testing and evaluation for potential use in hot, deep, sour wells. The Ni-Cr-Mo-W system was used in sour-gas wells in south Mississippi, Wyoming, and Mobile Bay. Corrosion data, mechanical properties, and resistance to environmental stress cracking are described for several oil country tubular goods (OCTG). Better understanding of metallurgical factors and of the role of alloying for enhanced resistance to corrosion, along with advanced in materials processing, are reviewed in terms of their impact on OCTG product reliability, improved safety, and cost-effectiveness","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"10 1","pages":"459-464"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82081537","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 a practical reservoir fluid-flow control system based on colloidal silica gel that was developed. Colloidal silica gel is an environmentally benign system that provides easy surface handling, reliable gel-time control at temperatures up to 250{degrees} F, and high in-situ performance. Extensive laboratory testing was completed and is discussed elsewhere. Colloidal silica gel has been used in 11 well work-overs for water-injection-profile modification (four wells), water-production control (three wells), and remedial casing repair (four wells). Only one of the four injection-well treatments was a clear-cut technical success, with failure typically caused by pressure parting the gel plug after the well treatment. Two of the three water-production-control jobs were technical and economic successes. Temporary success was achieved in three of the four casing-repair treatments.
{"title":"Oilfield applications of colloidal silica gel","authors":"J. J. Jurinak, L. Summers","doi":"10.2118/18505-PA","DOIUrl":"https://doi.org/10.2118/18505-PA","url":null,"abstract":"This paper reports on a practical reservoir fluid-flow control system based on colloidal silica gel that was developed. Colloidal silica gel is an environmentally benign system that provides easy surface handling, reliable gel-time control at temperatures up to 250{degrees} F, and high in-situ performance. Extensive laboratory testing was completed and is discussed elsewhere. Colloidal silica gel has been used in 11 well work-overs for water-injection-profile modification (four wells), water-production control (three wells), and remedial casing repair (four wells). Only one of the four injection-well treatments was a clear-cut technical success, with failure typically caused by pressure parting the gel plug after the well treatment. Two of the three water-production-control jobs were technical and economic successes. Temporary success was achieved in three of the four casing-repair treatments.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"4 1","pages":"406-412"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89328953","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}
A series of core damage experiments was conducted with filtrates containing various cement additives, such as dispersants and fluid-loss additives. Results clearly show that the extent and location of the permeability impairment varies, depending on the relative rate of particle precipitation and the residence time in the core. Results of the core-flow experiments are interpreted in conjunction with particle-size distribution and concentration results obtained in batch experiments. In this paper variations in the average particle size and the number concentration of particles with time in various compositions of cement filtrates are reported. These prove to be useful indicators of the extent and location of the damage observed in the cores.
{"title":"Formation Damage Caused by Cement Filtrates in Sandstone Cores","authors":"X. Yang, M. Sharma","doi":"10.2118/19305-PA","DOIUrl":"https://doi.org/10.2118/19305-PA","url":null,"abstract":"A series of core damage experiments was conducted with filtrates containing various cement additives, such as dispersants and fluid-loss additives. Results clearly show that the extent and location of the permeability impairment varies, depending on the relative rate of particle precipitation and the residence time in the core. Results of the core-flow experiments are interpreted in conjunction with particle-size distribution and concentration results obtained in batch experiments. In this paper variations in the average particle size and the number concentration of particles with time in various compositions of cement filtrates are reported. These prove to be useful indicators of the extent and location of the damage observed in the cores.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"218 1","pages":"399-405"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75808781","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 that placing a small fracture job before an inner-casing gravel pack has evolved as the preferred completion method for some reservoirs in Cook Inlet, AK. The hybrid completion gives the theoretical benefit of higher initial rates provided by the fracture and continuity of production provided by sand control.
{"title":"Evolution of a Hybrid Fracture/Gravel-Pack Completion: Monopod Platform, Trading Bay Field, Cook Inlet, Alaska","authors":"D. Grubert","doi":"10.2118/19401-PA","DOIUrl":"https://doi.org/10.2118/19401-PA","url":null,"abstract":"This paper reports that placing a small fracture job before an inner-casing gravel pack has evolved as the preferred completion method for some reservoirs in Cook Inlet, AK. The hybrid completion gives the theoretical benefit of higher initial rates provided by the fracture and continuity of production provided by sand control.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"197 1","pages":"395-398"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72828893","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}
When such factors as well response, return on stimulation costs, well cleanup, and sustained productivity are considered, it often becomes apparent that good wells are viable candidates for well stimulation. This paper discusses critical factors related to well-stimulation success, emphasizes that good wells possess the majority of these characteristics, and illustrates technical points with case histories.
{"title":"Good wells make the best candidates for well stimulation","authors":"A. R. Jennings","doi":"10.2118/19738-PA","DOIUrl":"https://doi.org/10.2118/19738-PA","url":null,"abstract":"When such factors as well response, return on stimulation costs, well cleanup, and sustained productivity are considered, it often becomes apparent that good wells are viable candidates for well stimulation. This paper discusses critical factors related to well-stimulation success, emphasizes that good wells possess the majority of these characteristics, and illustrates technical points with case histories.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"23 1","pages":"371-376"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77821639","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 various effects of CO{sub 2} on corrosion in general, a policy for fighting corrosion in offshore wells, the mechanisms of local CO{sub 2} attack, and a method of predicting the risks of CO{sub 2} corrosion in wells.
{"title":"Prediction of the Risks Of CO2 Corrosion in Oil and Gas Wells","authors":"J. Crolet, M. Bonis","doi":"10.2118/20835-PA","DOIUrl":"https://doi.org/10.2118/20835-PA","url":null,"abstract":"This paper discusses the various effects of CO{sub 2} on corrosion in general, a policy for fighting corrosion in offshore wells, the mechanisms of local CO{sub 2} attack, and a method of predicting the risks of CO{sub 2} corrosion in wells.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"175 1","pages":"449-453"},"PeriodicalIF":0.0,"publicationDate":"1991-11-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85083696","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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