Oilfield produced water containing a high concentration of total dissolved solids (TDS) and hardness can successfully be softened for use as oilfield steam-generator feedwater. At the Belridge in Kern County, CA, the combination of caustic softening and weak-acid cation exchange has been used to soften produced water containing 11,000 TDS and 550-ppm hardness to <1-ppm hardness. The resultant sludge containing calcium carbonate and magnesium hydroxide is concentrated by centrifuging and is disposed of in a landfill. Compared to the use of conventional strong-acid ion exchange followed by weak acid or weak acid followed by weak-acid ion exchange systems, the process offers the benefits of lower capital and chemical costs, partial silica removal, and elimination of liquid waste discharge
{"title":"A new caustic process for softening produced water for steam generation","authors":"R. J. Jan, T. Reed","doi":"10.2118/19759-PA","DOIUrl":"https://doi.org/10.2118/19759-PA","url":null,"abstract":"Oilfield produced water containing a high concentration of total dissolved solids (TDS) and hardness can successfully be softened for use as oilfield steam-generator feedwater. At the Belridge in Kern County, CA, the combination of caustic softening and weak-acid cation exchange has been used to soften produced water containing 11,000 TDS and 550-ppm hardness to <1-ppm hardness. The resultant sludge containing calcium carbonate and magnesium hydroxide is concentrated by centrifuging and is disposed of in a landfill. Compared to the use of conventional strong-acid ion exchange followed by weak acid or weak acid followed by weak-acid ion exchange systems, the process offers the benefits of lower capital and chemical costs, partial silica removal, and elimination of liquid waste discharge","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"74 1","pages":"199-202"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74140716","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}
Failure resulting from corrosion in gravity-water injection (GWI) wells is a major concern in the Abqaiq field, Saudi Arabia. This paper presents alternatives investigated to prolong the life of the wells, results of in-situ corrosion tests of 13% Cr steel alloy, and studies of the effect of coupling 13% Cr alloy with carbon steel.
{"title":"Corrosion-resistant tubulars for prolonging gravity-water-injection well life","authors":"M. Farooqui, Scott D. Holland","doi":"10.2118/21365-PA","DOIUrl":"https://doi.org/10.2118/21365-PA","url":null,"abstract":"Failure resulting from corrosion in gravity-water injection (GWI) wells is a major concern in the Abqaiq field, Saudi Arabia. This paper presents alternatives investigated to prolong the life of the wells, results of in-situ corrosion tests of 13% Cr steel alloy, and studies of the effect of coupling 13% Cr alloy with carbon steel.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"72 1","pages":"149-154"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89407135","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}
Coiled-tubing cementing has been practiced successfully on the Alaskan North Slope for several years. This paper discusses the special problems faced when this technology was applied to offshore U.S. gulf coast operations. The innovative solutions and procedures developed to improve the economic and technical success of coiled-tubing cementing are also discussed. Comparative laboratory and computer studies, as well as field case histories, will be presented to show the economic merit of this technology.
{"title":"New technologies address the problem areas of coiled-tubing cementing","authors":"R. B. Carpenter","doi":"10.2118/20426-PA","DOIUrl":"https://doi.org/10.2118/20426-PA","url":null,"abstract":"Coiled-tubing cementing has been practiced successfully on the Alaskan North Slope for several years. This paper discusses the special problems faced when this technology was applied to offshore U.S. gulf coast operations. The innovative solutions and procedures developed to improve the economic and technical success of coiled-tubing cementing are also discussed. Comparative laboratory and computer studies, as well as field case histories, will be presented to show the economic merit of this technology.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"63 1","pages":"137-143"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76501938","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 dynamic risk analysis was performed on four different gas-lift completions using a computer simulator. In this paper results are presented to allow comparison of the designs in terms of blowout risk and minor leakage during production and to provide insight into the effect of critical components and operations on the overall well safety.
{"title":"Blowout Risk Analysis of Gas-Lift Completions","authors":"D. D. Grassick, P. S. Kallos, S. Dean, S. King","doi":"10.2118/20916-PA","DOIUrl":"https://doi.org/10.2118/20916-PA","url":null,"abstract":"A dynamic risk analysis was performed on four different gas-lift completions using a computer simulator. In this paper results are presented to allow comparison of the designs in terms of blowout risk and minor leakage during production and to provide insight into the effect of critical components and operations on the overall well safety.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"46 1","pages":"172-180"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88922872","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 potential for scale formation after seawater injection must be carefully studied when a new oil field is being developed in order to provide proper input data for the basic engineering design. This paper presents the results of a study of several facets of scale occurrence and control for a developing North Sea field characterized by a high-salinity, high-barium (up to 1,000 ppm) formation brine. The results justify consideration of new technologies, such as treatment of the seawater to reduce the sulfate content.
{"title":"Scale Prediction and Laboratory Evaluation of BaSO4 Scale Inhibitors for Seawater Flood in a High-Barium Environment","authors":"E. Mazzolini, L. Bertero, C. S. Truefitt","doi":"10.2118/20894-PA","DOIUrl":"https://doi.org/10.2118/20894-PA","url":null,"abstract":"The potential for scale formation after seawater injection must be carefully studied when a new oil field is being developed in order to provide proper input data for the basic engineering design. This paper presents the results of a study of several facets of scale occurrence and control for a developing North Sea field characterized by a high-salinity, high-barium (up to 1,000 ppm) formation brine. The results justify consideration of new technologies, such as treatment of the seawater to reduce the sulfate content.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"10 1","pages":"186-192"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87509754","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 application of water-soluble polymers in the oil industry (e.g., fluid-loss reducer, polymer flooding, and water-based drilling muds) requires hydrosoluble polymers to be compatible with corrodible materials. The behavior of polyacrylamides and xanthans in the presence of various materials used for oil production (steel, stainless steel, carbon steel, and Inconel) has been studied vs. different water salinities, oxygen contents, and temperatures. The influence of such commonly used additives as oxygen scavengers and sequestrants on corrosion and polymer stability has also been investigated. For both types of polymers, as corrosion occurs under anaerobic conditions, strong interactions between polymer chains and divalent cations (Fe{sup 2+} to Fe{sup 2+}) are observed. Such interactions also depend on polymer quality. In the presence of oxygen, corrosion induces a molecular-weight degradation of the polymer followed by a gelation process for xanthan. Some additives may accelerate the transformation of Fe{sup 2+} to Fe{sup 3+}, thus inducing polymer degradation, but this reaction depends on the nature of the chelating agent. These results provide guidelines for the implementation of polymers in oil production, including the selection of materials, water treatment, or mud formulation.
{"title":"Compatibility of Hydrosoluble Polymers With Corrodible Materials","authors":"A. Audibert, J. Lecourtier","doi":"10.2118/21026-PA","DOIUrl":"https://doi.org/10.2118/21026-PA","url":null,"abstract":"This paper reports that application of water-soluble polymers in the oil industry (e.g., fluid-loss reducer, polymer flooding, and water-based drilling muds) requires hydrosoluble polymers to be compatible with corrodible materials. The behavior of polyacrylamides and xanthans in the presence of various materials used for oil production (steel, stainless steel, carbon steel, and Inconel) has been studied vs. different water salinities, oxygen contents, and temperatures. The influence of such commonly used additives as oxygen scavengers and sequestrants on corrosion and polymer stability has also been investigated. For both types of polymers, as corrosion occurs under anaerobic conditions, strong interactions between polymer chains and divalent cations (Fe{sup 2+} to Fe{sup 2+}) are observed. Such interactions also depend on polymer quality. In the presence of oxygen, corrosion induces a molecular-weight degradation of the polymer followed by a gelation process for xanthan. Some additives may accelerate the transformation of Fe{sup 2+} to Fe{sup 3+}, thus inducing polymer degradation, but this reaction depends on the nature of the chelating agent. These results provide guidelines for the implementation of polymers in oil production, including the selection of materials, water treatment, or mud formulation.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"21 1","pages":"193-198"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79172611","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}
Eleven hydraulic fracture treatments were performed in deep (3300 to 3800 m (10,830 to 12,470 ft)), extremely high-temperature (180 to 195{degrees}C (356 to 383{degrees}F)), naturally fissured, gas-condensate reservoirs. Formation permeabilities at the fractured-well locations range from 0.003 to 0.2 md, while the initial formation pressure gradient is about 0.13 bar/m (0.57 psi/ft). The producing fluid is high-gravity gas (0.83 to 1.15 to air) and contains up to 22% CO{sub 2} and up to 4% H{sub 2}S. Job sizes have ranged from 300 to 2000 m{sup 3} (80,000 to 528,400 gal) of fluid and 50 to 600 Mg (110,130 to 1,321,590 lbm) of high-strength proppant. This paper emphasizes the general approach to well completion and stimulation treatment design, treatment execution, and evaluation. Interesting items include the engineering of the fracturing fluids to sustain their viscosity at the extreme temperatures and to reduce leakoff in these highly fissured formations. An outline of the reservoir description is also given. Post-treatment well production has been excellent in most cases. Well PI's increased from 0.01 to 0.6 m{sup 3}/d {center dot} bar{sup 2} (0.0017 to 0.1 scf/D-psi{sup 2}) to 0.235 to 7.83 m{sup 3}/d {center dot} bar{sup 2} (0.04 to 1.3 scf/D-psi{sup 2}). Treatment resultsmore » suggest that leakoff can be controlled with particulate agents, that delayed crosslinking is the only way to execute these treatments, and that hydraulic fracturing can greatly improve the production from naturally fissured formations. Fracture design and the predicted well production are compared with post-treatment performances in selected wells.« less
{"title":"Fracturing of High-Temperature, Naturally Fissured, Gas-Condensate Reservoirs","authors":"M. Čikeš, M. Economides","doi":"10.2118/20973-PA","DOIUrl":"https://doi.org/10.2118/20973-PA","url":null,"abstract":"Eleven hydraulic fracture treatments were performed in deep (3300 to 3800 m (10,830 to 12,470 ft)), extremely high-temperature (180 to 195{degrees}C (356 to 383{degrees}F)), naturally fissured, gas-condensate reservoirs. Formation permeabilities at the fractured-well locations range from 0.003 to 0.2 md, while the initial formation pressure gradient is about 0.13 bar/m (0.57 psi/ft). The producing fluid is high-gravity gas (0.83 to 1.15 to air) and contains up to 22% CO{sub 2} and up to 4% H{sub 2}S. Job sizes have ranged from 300 to 2000 m{sup 3} (80,000 to 528,400 gal) of fluid and 50 to 600 Mg (110,130 to 1,321,590 lbm) of high-strength proppant. This paper emphasizes the general approach to well completion and stimulation treatment design, treatment execution, and evaluation. Interesting items include the engineering of the fracturing fluids to sustain their viscosity at the extreme temperatures and to reduce leakoff in these highly fissured formations. An outline of the reservoir description is also given. Post-treatment well production has been excellent in most cases. Well PI's increased from 0.01 to 0.6 m{sup 3}/d {center dot} bar{sup 2} (0.0017 to 0.1 scf/D-psi{sup 2}) to 0.235 to 7.83 m{sup 3}/d {center dot} bar{sup 2} (0.04 to 1.3 scf/D-psi{sup 2}). Treatment resultsmore » suggest that leakoff can be controlled with particulate agents, that delayed crosslinking is the only way to execute these treatments, and that hydraulic fracturing can greatly improve the production from naturally fissured formations. Fracture design and the predicted well production are compared with post-treatment performances in selected wells.« less","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"12 1","pages":"226-232"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88262710","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 compares the steam stability of common gravel-packing materials. The scope was limited to one set of downhole conditions. Results indicated that none of the commonly used materials were entirely satisfactory, but another material not normally used in the petroleum industry was found to give excellent results.
{"title":"Evaluation of Steam Resistance of Gravel-Packing Materials","authors":"J. Weaver, J. Knox","doi":"10.2118/20025-PA","DOIUrl":"https://doi.org/10.2118/20025-PA","url":null,"abstract":"This paper compares the steam stability of common gravel-packing materials. The scope was limited to one set of downhole conditions. Results indicated that none of the commonly used materials were entirely satisfactory, but another material not normally used in the petroleum industry was found to give excellent results.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"12 4 1","pages":"155-159"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75517808","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 major problem experienced in pumping thermal wells is low volumetric efficiencies resulting from steam and noncondensable gas interference. This paper examines the results of physical simulations performed on a full-scale sucker-rod pump test facility and numerical simulations that used an equation of state (EOS) to predict theoretical volumetric pump efficiencies.
{"title":"Simulation of thermal-well sucker-rod pumping","authors":"A. Wong, T. Sudol","doi":"10.2118/19714-PA","DOIUrl":"https://doi.org/10.2118/19714-PA","url":null,"abstract":"A major problem experienced in pumping thermal wells is low volumetric efficiencies resulting from steam and noncondensable gas interference. This paper examines the results of physical simulations performed on a full-scale sucker-rod pump test facility and numerical simulations that used an equation of state (EOS) to predict theoretical volumetric pump efficiencies.","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"1 1","pages":"181-185"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79625055","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}
Oryx Energy Co. used three basic completion techniques and various combinations of them to complete 20 horizontal wells in the Pearsall Austin Chalk. The completion method selected is based on a general set of guidelines. Additionally, equipment selection and various types of workover operations are reviewed
{"title":"Completion techniques for horizontal wells in the Pearsall Austin Chalk","authors":"C. D. Pope, P. Handren","doi":"10.2118/20682-PA","DOIUrl":"https://doi.org/10.2118/20682-PA","url":null,"abstract":"Oryx Energy Co. used three basic completion techniques and various combinations of them to complete 20 horizontal wells in the Pearsall Austin Chalk. The completion method selected is based on a general set of guidelines. Additionally, equipment selection and various types of workover operations are reviewed","PeriodicalId":22020,"journal":{"name":"Spe Production Engineering","volume":"20 3-4 1","pages":"144-148"},"PeriodicalIF":0.0,"publicationDate":"1992-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72757968","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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