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Corrosion Of Gathering Pipelines In Oil And Gas Field And Its Mitigation Measures In China

Picture for Corrosion Of Gathering Pipelines In Oil And Gas Field And Its Mitigation Measures In China
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The exploration and development of oil and gas resources towards the direction of ultra-deep, low permeability, and unconventional in China. In addition, some oil and gas fields have developed into the middle or late stage, the application of various EOR technologies, such as acid fracturing, CO2 flooding, air foam flooding and polymer flooding, resulting in the service environment of oil and gas gathering pipelines becoming more and more complex and harsh, such as high temperature, high pressure, high H2S/CO2, Cl- and bacteria, corrosion failures became one of the biggest challenges of oil and gas gathering pipelines.

Product Number: 51322-17741-SG
Author: Anqing Fu, Juntao Yuan, Zihan Chen, Xuanpeng Li, Naixin Lv, Wensheng Li, Lei Fan, Houbu Li
Publication Date: 2022
Industries: Corrosion Monitoring and Control , Coatings and Linings , Coatings
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$20.00

The service environment of oil and gas gathering pipelines becoming more and more complex and harsh, resulting in frequent failure, which not only causes the loss of oil and gas resources, but also the environmental and safety issues. Therefore, this paper focuses on the internal corrosion characteristics and most concerned issues of the oil and gas gathering pipelines and its mitigation measures. Firstly, several typical corrosion-induced failures of oil and gas gathering pipelines are introduced, moreover, the internal corrosion characteristics and advanced understanding of corrosion causes and mechanisms are analyzed. Then, internal corrosion control techniques including inhibitor, coating, clad pipe, non-metallic pipe, and life extension techniques including PE pipe insertion lining repair, air pressure extrusion coating repair, local repair and reinforcement were introduced.

The service environment of oil and gas gathering pipelines becoming more and more complex and harsh, resulting in frequent failure, which not only causes the loss of oil and gas resources, but also the environmental and safety issues. Therefore, this paper focuses on the internal corrosion characteristics and most concerned issues of the oil and gas gathering pipelines and its mitigation measures. Firstly, several typical corrosion-induced failures of oil and gas gathering pipelines are introduced, moreover, the internal corrosion characteristics and advanced understanding of corrosion causes and mechanisms are analyzed. Then, internal corrosion control techniques including inhibitor, coating, clad pipe, non-metallic pipe, and life extension techniques including PE pipe insertion lining repair, air pressure extrusion coating repair, local repair and reinforcement were introduced.

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Corrosion Inhibitors Use: Case Study For Guinea Gulf Assets Application

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Author: Alvaro Mpaka Sousa, Laurent Dehays, Francisco Mateus Garcia, Mioara Stroe, Raquel Eduarda Araujo
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Carbon steel (CS) material is widely used for the equipment in oil and gas production industry due to its mechanical properties associated with a relatively low cost, compared to other materials. Depending on the corrosiveness of the fluid that is vehiculated, the use of carbon steel is generally associated with the injection of a corrosion inhibitor (CI) in order to mitigate internal corrosion. Corrosion inhibitors are generally used in continuous injection at an injection rate that is depending on the corrosiveness of the fluid. Based on the operational feedback, the internal standards are recommending for multiphase pipelines CI injection rates in the range of 50 - 70 ppm for temperature below 80°C of and of 150 to 200ppm for temperatures above 100°C. These injection dosages are typical values that are considered in the laboratory tests for the qualification of the CI and they are adjusted on-site based on the monitoring results.
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Corrosion Management Learnings For Atmospheric Storage Tanks

Product Number: 51322-17951-SG
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The terminal is subdivided for Oil, Gas and Produced Water plants. Each of these plants has number of storage tanks. The age of the tanks varies between 15-25 years.  The products held within these tanks varies, from crude oil, condensate, produced water, potable water, to off spec oil and diesel fuel.

Most of the tanks within the facility have a similar CP arrangement and design.  Each tank base is protected by an impressed current grid mesh anode buried in compacted, clean, sand backfill beneath the tank base and is powered by a transformer-rectifier placed outside the bund wall or within an electrical switch room.  Permanent reference electrodes are installed beneath all tank bases to enable accurate potential measurements. Reference electrodes vary from Copper/Copper Sulphate, Silver/Silver Chloride to Zinc.  
Corrosion Investigation Of Five Stainless Steels In Oil-Gas-Water Multiphase Flow Containing H2S, CO2 And Chloride
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Corrosion Investigation Of Five Stainless Steels In Oil-Gas-Water Multiphase Flow Containing H2S, CO2 And Chloride

Product Number: 51322-18121-SG
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M. B. Kermani pointed out that 25% of equipment failures in the oil and gas industry are caused by corrosion, and more than half of corrosion events are related to produced fluids containing CO2 and H2S. In recent years, the exploitation of sour oil and gas fields (containing H2S or H2S/CO2 mixture) has become more and more common, and prominent problems such as tubing ruptures caused by pitting and uniform corrosion have appeared. In oil fields containing CO2 and H2S, local corrosion is a key factor restricting the selection of tubing and casing materials. In an oilfield containing CO2 and H2S in the Middle East, the authors corroded coupons on site, and carried out indoor simulation experiments for the problems found in the field test. The authors systematically studied 13Cr, S13Cr, 22Cr, 25Cr and 2550 in the presence of H2S, CO2 and high mineralization. 
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