HOME   Cart(0)   Quotation   About-Us Tax PDFs Standard-List Powered by Google www.ChineseStandard.net Database: 189760 (2 Nov 2024)

GB/T 23258-2020 Related PDF English (GB/T 23258-2009)

GB/T 23258-2020 (GB/T23258-2020, GBT 23258-2020, GBT23258-2020) & related versions
Standard IDContents [version]USDSTEP2[PDF] delivered inStandard Title (Description)See DetailStatusSimilar PDF
GB/T 23258-2020English205 Add to Cart 0-9 seconds. Auto delivery. Standard practice controlling internal corrosion in steel pipelines and piping systems GB/T 23258-2020 Valid GBT 23258-2020
GB/T 23258-2009English559 Add to Cart 3 days Standard practice controlling internal corrosion in steel pipelines GB/T 23258-2009 Obsolete GBT 23258-2009
Buy with any currencies (Euro, JPY, KRW...): GB/T 23258-2020    Preview this PDF: GB/T 23258-2020



GB/T 23258-2020 GB NATIONAL STANDARD OF THE PEOPLE’S REPUBLIC OF CHINA ICS 75.200 CCS E 98 Replacing GB/T 23258-2009 Standard practice controlling internal corrosion in steel pipelines and piping systems ISSUED ON: NOVEMBER 19, 2020 IMPLEMENTED ON: JUNE 01, 2021 Issued by: State Administration for Market Regulation; Standardization Administration of the PRC. Table of Contents Foreword ... 3  1 Scope ... 5  2 Normative references ... 5  3 Terms and definitions ... 6  4 Basic provisions ... 7  5 Process control measures ... 8  5.1 Process control ... 8  5.2 Treatment of pipeline transportation medium ... 8  5.3 Pigging ... 9  5.4 Sand erosion control ... 9  6 Material selection ... 9  6.1 General ... 9  6.2 Oil and gas pipelines ... 10  6.3 Seawater pipelines ... 12  7 Chemical agents and filling ... 14  7.1 General ... 14  7.2 Corrosion inhibitor ... 14  7.3 Bactericide ... 15  7.4 Scale inhibitor and other agents ... 15  8 Coating and lining ... 16  8.1 Coating ... 16  8.2 Lining corrosion-resistant alloy material ... 16  8.3 Lining non-metallic material ... 17  8.4 Patching and jointing process ... 17  9 Corrosion control management and evaluation... 18  9.1 Corrosion control management plan ... 18  9.2 Corrosion monitoring and testing ... 19  9.3 Effect evaluation ... 20  10 Record ... 20  Appendix A (Informative) Physical and chemical property indexes of glass lining for oilfield gathering and water injection pipelines ... 22  Bibliography ... 23  Foreword This document is drafted in accordance with GB/T 1.1-2020 "Directives for standardization - Part 1: Rules for the structure and drafting of standardizing documents". This document replaces GB/T 23258-2009 "Standard practice controlling internal corrosion in steel pipelines". Compared with GB/T 23258-2009, in addition to editorial changes, the main technical changes are as follows: a) Modify the normative references (see Clause 2; Clause 2 of the 2009 edition); b) Revise the scope of process control measures; ADD content related to sand erosion control (see Clause 5; Clause 4 and Clause 5 of the 2009 edition); c) ADD content related to material selection, including general requirements for material selection; material selection for oil and gas gathering and processing systems, injection systems and seawater piping systems; and related content for galvanic corrosion control (see Clause 6); d) ADD relevant content such as bactericides and scale inhibitors (see Clause 7); e) Revise the relevant content of coating and lining control measures (see Clause 8; Clause 5 of the 2009 edition); f) ADD content related to corrosion control management and evaluation (see Clause 9); g) Revise the relevant content of on-line corrosion monitoring (see Clause 9; Clause 6 of the 2009 edition). This document was proposed by and shall be under the jurisdiction of Technical Committee 355 on Petroleum of Standardization Administration of China (SAC/TC 355). Drafting organizations of this document: China Petroleum Engineering & Construction Corporation Southwest Company, China National Petroleum Corporation Tarim Oilfield Branch, Sinopec Petroleum Engineering Corporation, CNOOC Research Institute Co., Ltd., Xi'an Changqing Technology Engineering Co., Ltd., PetroChina Southwest Oil & Gasfield Company Natural Gas Research Institute. Main drafters of this document: Shi Daiyan, Du Tonglin, Zhang Renyong, Ou Li, Chang Wei, Jiang Fang, Zhang Zhihao, Li Linhui, Mao Xueqiang, Li Shan, Li Tianlei, Cao Xiaoyan, Xian Ning, Meng Bo, Fu Heping, Yang Shuo, Wang Yaxi, Xu Jiashuang. The previous editions of this document and the documents replaced are as follows: - It was first published as GB/T 23258-2009 in 2009; - This is the first revision. Standard practice controlling internal corrosion in steel pipelines and piping systems 1 Scope This document specifies the requirements of process control measures, material selection, chemical agents and filling, coating and lining, corrosion control management and evaluation for internal corrosion in steel pipelines and piping systems. This document applies to steel pipelines and piping systems that transport media such as oil, natural gas, and water in oil and gas production. 2 Normative references The contents of the following documents, through normative references in this text, constitute indispensable provisions of this document. Among them, for dated references, only the edition corresponding to that date applies to this document. For undated references, the latest edition (including all amendments) applies to this document. GB/T 20972 (all parts) Petroleum and natural gas industries - Materials for use in H2S-containing environments in oil and gas production HG/T 4375 Modified material of ultra-high molecular weight polyethylene for pipe lining SY/T 0321 Standard for steel mortar lining for steel pipelines SY/T 0442 Technical standard for internal fusion-bonded epoxy coating of steel pipe SY/T 0457 Technical specification for anticorrosion in liquid epoxy coating of steel pipeline SY/T 0546 Technical specification for collection and identification of corrosion products SY/T 0599 Specification for sulfide stress cracking and stress corrosion cracking resistant metallic materials for natural gas surface facilities SY/T 0611 Specification of controlling internal corrosion in gathering system An alloy used to resist uniform corrosion and local corrosion in a corrosive environment where carbon steel is subject to corrosion. 3.4 Glass lining A layer of vitreous enamel formed on the inner surface of the metal substrate by high-temperature cladding. 4 Basic provisions 4.1 The internal corrosion control of the pipelines includes measures such as process control, selection of corrosion-resistant materials, addition of chemical agents, and the use of internal coating or lining. One or more control measures should be taken. The internal corrosion control measures shall be determined according to the correlation and influence between the various corrosion control measures, as well as the applicability, feasibility and economy. 4.2 Before the internal corrosion control plan and measures are determined, corrosion mechanism analysis and corrosion evaluation shall be carried out. According to factors such as the corrosiveness of the transportation medium and operating conditions, it shall carry out a comprehensive evaluation. The evaluation of internal corrosion in the pipeline shall be graded according to the indexes in Table 1. The grade shall be determined based on the most serious result of uniform corrosion and pitting corrosion. Table 1 -- Evaluation index of internal corrosion in the pipeline Values in millimeters per year 4.3 The determination of corrosive components and impurities in the transportation medium should include: water, carbon dioxide, hydrogen sulfide, chloride, oxygen, organic acids, elemental sulfur, bacteria, mercury and its compounds, solids or precipitates, and other sulfur-containing compounds. The collection of parameters for operating conditions shall include: temperature, pressure, flow rate, water content, oil and gas content, etc. 4.4 The technical requirements for controlling internal corrosion in gathering system for highly hydrogen sulfide gas field shall meet the requirements of SY/T Serious Medium Low Level Pitting rate Average corrosion rate Item More serious 5.2.3 For systems containing acidic media such as hydrogen sulfide and carbon dioxide, separation measures should be taken, to remove hydrogen sulfide and carbon dioxide from the pipeline transportation media. 5.2.4 For severely-corroded produced water and water injection pipelines, measures, such as airtight oxygen isolation, water quality modification, and pre- oxidation processes, can be used to slow down the corrosion. If dissolved oxygen is the main corrosion factor, a closed treatment process should be adopted. If acid gas is the main corrosion factor, pre-oxidation and water quality modification process should be adopted. If the low pH value causes severe corrosion, the pH value should be adjusted. 5.3 Pigging 5.3.1 For pipelines with deposits which can easily cause corrosion, pigging measures should be adopted, to remove deposits. 5.3.2 Based on the corrosion of deposits and bacteria on the pipeline, it shall establish a reasonable pigging cycle. 5.3.3 Pigging measures should be used in conjunction with other corrosion control measures, such as adding corrosion inhibitors and dehydration. When pigging, it shall avoid adversely affecting the inner coating. 5.4 Sand erosion control 5.4.1 For oil and gas transportation pipelines containing sand, it is advisable to install a desander at the front end. 5.4.2 For pipelines conveying liquid media containing sand, the liquid flow rate should be controlled. 5.4.3 For pipe sections and fittings that are prone to erosion corrosion, one or more of the following measures to control erosion corrosion should be adopted: a) Long-radius pipe fittings such as elbows, blind tees; b) Erosion corrosion-resistant metal materials; c) Apply anti-erosion coating. 6 Material selection 6.1 General 6.1.1 Material selection shall be determined through technical and economic 6.3.4 The connection of the pipelines and fittings of corrosion-resistant alloy material should not use threaded connection. 6.3.5 Graphite-containing gaskets shall not be used in metal seawater piping systems. 7 Chemical agents and filling 7.1 General 7.1.1 Chemicals agents used for corrosion control, such as corrosion inhibitors, bactericides, deoxidizers, and scale inhibitors, shall be selected according to the working conditions and the corrosiveness of the medium. 7.1.2 The type and filling volume of chemical agents shall be determined through screening, laboratory evaluation, and field verification, etc. 7.1.3 Before filling the chemical agent, the compatibility of the various agents in the system shall be evaluated. 7.2 Corrosion inhibitor 7.2.1 The corrosion inhibitor shall be selected based on the following factors: a) Corrosion type and corrosion factor; b) Compatibility with pipeline transportation media and other chemical agents; c) Corrosion inhibition performance, physical and chemical properties and use conditions of corrosion inhibitor; d) Operability of storage, transportation, use and filling; e) Influence on the subsequent process. 7.2.2 The performance evaluation of corrosion inhibitors for oil and gas pipelines should meet the requirements of SY/T 7025. The performance evaluation of corrosion inhibitors for produced water should meet the requirements of SY/T 5273. 7.2.3 The filling method and technical requirements of corrosion inhibitor for oil and gas pipelines shall meet the requirements of SY/T 7408. 7.2.4 The material of the corrosion inhibitor filling device shall be adapted to the working conditions of continuous contact with the corrosion inhibitor. Carbon steel or stainless steel should be used. Small-diameter pipelines should be 8 Coating and lining 8.1 Coating 8.1.1 The inner coating shall be selected based on the following factors: a) Corrosiveness of pipeline transportation medium; b) Aggressiveness of dirt, impurities, additives, etc.; c) Adhesion, toughness and ductility to the pipe wall; d) Influence on the pipeline transportation medium. 8.1.2 According to the degree of corrosion of the transportation medium, the type, structure and thickness of the inner coating shall be determined. 8.1.3 The inner coating pipe should be prefabricated in the factory. When liquid epoxy coating is used for the inner coating, the material properties, construction coating, and quality test shall meet the requirements of SY/T 0457. When epoxy powder coating is used for the inner coating, the material properties, construction coating, and quality test shall meet the requirements of SY/T 0442. 8.1.4 When the inner coating adopts the overall extrusion coating process at the construction site, it shall meet the requirements of SY/T 4076. 8.1.5 When the pipeline transportation temperature is higher than 80 °C, high- temperature-resistant coatings shall be selected. The long-term use temperature shall be determined through tests in conjunction with the on-site conditions. 8.1.6 The inner corrosion-resistant coating of high-pressure transportation pipelines higher than 12 MPa shall be subjected to high-pressure resistance tests under simulated working conditions. After the test, the permeability and adhesion of the coating shall meet the requirements of working conditions. 8.2 Lining corrosion-resistant alloy material 8.2.1 Corrosion-resistant alloy composite pipe includes two forms: inner cladding or lining. The process pipeline of the station should be the inner- cladded composite pipe. The line pipeline should be the lining composite pipe or the inner-cladded composite pipe. Pipe fittings, perforated pipelines, bends, and pipelines for cutting should adopt inner-cladded composite pipes. 8.2.2 Corrosion-resistant alloy composite pipes shall be inspected in the factory for chemical composition, bonding strength, and corrosion resistance, etc. The of the patch, and construction environment, etc. 8.4.3 During the construction of the on-site inner coating patch, the selected patching materials and construction methods shall be subject to process evaluation. The corresponding inner coating patch construction plan and quality control measures shall be prepared. The quality of the inner coating patch shall not be lower than the inner coating of the pipe body. 8.4.4 For small-caliber pipelines and golden openings with inner anticorrosion layer of liquid/solid paint, it is advisable to adopt the method of pipe end corrosion-resistant alloy surfacing and lining joint patching. The surfacing material shall be selected according to the corrosiveness of the medium. 316 L, duplex stainless steel, nickel-based alloy, etc. should be selected. Lining joints should select anticorrosion steel short-joint, FRP, polytetrafluoroethylene and other materials. 9 Corrosion control management and evaluation 9.1 Corrosion control management plan 9.1.1 When pipelines are prone to internal corrosion, internal corrosion control management plans should be prepared. 9.1.2 The internal corrosion control management plan should include the following: a) Overview of the pipelines; b) Corrosion control objectives and indexes; c) Measurement and analysis of internal corrosion and related parameters; d) Corrosion mechanism and corrosion characteristics; e) Corrosion risk assessment; f) Current status and plan of internal corrosion control measures; g) Corrosion control engineering construction quality and design modification; h) Testing/monitoring plan; i) Evaluation and countermeasures of corrosion control effect; j) Feedback and continuous improvement; k) Data recording and storage. and tested for analysis. The collection and identification of corrosion products shall comply with SY/T 0546. 9.2.10 Internal corrosion testing methods include ultrasonic thickness measurement, electromagnetic ultrasonic thickness measurement, ultrasonic C-scan, X-ray, ultrasonic guided-wave, magnetic flux leakage testing, ultrasonic testing, etc. They shall be selected according to the specific conditions of the pipeline. 9.3 Effect evaluation 9.3.1 Based on the results of corrosion monitoring, internal testing, internal corrosion direct evaluation, etc., combined with production and operation conditions and changes in media properties, the effect of internal corrosion control of the pipelines shall be evaluated. 9.3.2 The evaluation of the effect of corrosion control in the pipeline shall be carried out periodically. The effect evaluation shall be based on the evaluation results of the previous cycle; the evaluation plan for the next cycle shall be formulated. 10 Record 10.1 Internal corrosion control records of steel pipelines and piping systems shall include information and records related to internal corrosion control in design, construction, operation and maintenance, and testing and evaluation. 10.2 Information and records related to design and construction mainly include the following: a) Pipeline transportation medium components and corrosive medium; b) Overview of the pipeline, such as material, diameter, wall thickness, length, pressure rating, temperature, inner coating and lining; c) Corrosion control measures selected, such as dehydration, deoxidation, and corrosion inhibitor injection; d) Type, structure, technical requirements and construction technology of inner coating or lining; e) Material and process technical requirements of the patch and joint; f) Construction process and quality control records of corrosion control measures; ......


GB/T 23258-2009 Standard practice controlling internal corrosion in steel pipelines ICS 75.200 E98 National Standards of People's Republic of China Steel pipeline corrosion control practices within Posted 2009-03-16 2009-10-01 implementation Administration of Quality Supervision, Inspection and Quarantine of People's Republic of China Standardization Administration of China released Foreword This standard corresponds to United States International Association of Corrosion Engineers Standard NACESP0106-2006 "steel pipes and pipe systems internal corrosion Control Standards "and NACESP0106-2006 non-equivalent. Appendix A of this standard is the data appendix. The standard proposed by China National Petroleum Corporation. This standard by the National Standardization Technical Committee of Oil and Gas. This standard is drafted by. China Petroleum Engineering Co., Ltd. Southwest Branch. The main drafters of this standard. Shi Dai Yan, Jiang put to the wave, while Yun Yan, Tang Xiaoyong, Cao Xiaoyan, text on behalf of the dragon, Chen Rupei, Du Tong Lin, Fu Heping, Yang Shuo, Du Yi, Li tenrai, Wang Qin Jin, Yin Ming Xue, Li Zuan. Steel pipeline corrosion control practices within 1 Scope This standard specifies design criteria within the corrosion control of steel pipe inner corrosion control method corrosion detection and monitoring of the effect evaluation, etc. Yung basic requirements. This standard applies to steel pipeline transporting oil, gas, water and other media. 2 Normative references The following documents contain provisions which, through reference in this standard and become the standard terms. For dated references, subsequent Amendments (not including errata content) or revisions do not apply to this standard, however, encourage the parties to the agreement are based on research Whether the latest versions of these documents. For undated reference documents, the latest versions apply to this standard. Removal of corrosion products from corrosion specimens GB/T 16545 of metals and alloys SY/T 0442 in the steel pipeline fusion bonded epoxy powder coating technology standards SY/T 0457 steel pipeline liquid epoxy internal coating technology standards Collection and identification of SY/T 0546 corrosion products Pipeline operating procedures SY/T 5536 Crude Oil SY/T 5922 Gas Pipeline Operations Specifications Within SY/T 6623 or liner coated corrosion-resistant alloy composite pipe specifications Immersion method JB/T 7901 uniform corrosion of metallic materials laboratory 3 Terms and Definitions The following terms and definitions apply to this standard. 3.1 The content of iron ions in water mass (mg/L) of water per unit volume usually indicates iron ions, may indicate corrosion pipeline system Activity. 3.2 The water content of manganese ions, mass (mg/L) of water per unit volume is usually expressed manganese ions. NOTE. ferroalloy materials for oilfield downhole equipment in the manganese content is generally 0.5% to 1.5%. So if all of the iron ions and manganese ions are rot Erosion caused by water instead of the original output, the share of output of manganese and iron ions in water is about 100. 3.3 Installed on both ends of the main channel or bypass flanged short pipe length is generally 0.3m ~ 1m. Can be periodically removed for internal For detection of the piping system to obtain information corrosion. Short tube material should be consistent with the main pipe material. 3.4 Applying an electric field in a short tube pipe metal loss in the pipe wall due to corrosion caused by the electric field changes, the change of the electric field measurements To calculate the change in the corrosion of pipelines. ......

BASIC DATA
Standard ID GB/T 23258-2020 (GB/T23258-2020)
Description (Translated English) Standard practice controlling internal corrosion in steel pipelines and piping systems
Sector / Industry National Standard (Recommended)
Classification of Chinese Standard E98
Classification of International Standard 75.200
Word Count Estimation 14,134
Date of Issue 2020-11-19
Date of Implementation 2021-06-01
Older Standard (superseded by this standard) GB/T 23258-2009
Drafting Organization China Petroleum Engineering Construction Co., Ltd. Southwest Branch, China National Petroleum Corporation Tarim Oilfield Branch, Sinopec Petroleum Engineering Design Co., Ltd., CNOOC Research Institute Co., Ltd., Xi'an Changqing Technology Engineering Co., Ltd., China National Petroleum Corporation Company's Southwest Oil and Gas Field Branch Natural Gas Research Institute
Administrative Organization National Petroleum and Natural Gas Standardization Technical Committee (SAC/TC 355)
Regulation (derived from) National Standard Announcement No. 26 of 2020
Proposing organization National Petroleum and Natural Gas Standardization Technical Committee (SAC/TC 355)
Issuing agency(ies) State Administration for Market Regulation, National Standardization Administration

BASIC DATA
Standard ID GB/T 23258-2009 (GB/T23258-2009)
Description (Translated English) Standard practice controlling internal corrosion in steel pipelines
Sector / Industry National Standard (Recommended)
Classification of Chinese Standard E98
Classification of International Standard 75.200
Word Count Estimation 14,110
Date of Issue 2009-03-16
Date of Implementation 2009-10-01
Adopted Standard NACE SP 0106-2006, NEQ
Drafting Organization China Petroleum Engineering Co., Ltd. Southwest Branch
Administrative Organization National Standardization Technical Committee of Petroleum and Natural Gas
Regulation (derived from) National Standard Approval Announcement 2009 No.2 (Total No.142)
Proposing organization Petroleum and Natrual Gas Corporation of China
Issuing agency(ies) Administration of Quality Supervision, Inspection and Quarantine of People's Republic of China; Standardization Administration of China
Summary This standard specifies the design criteria within the corrosion control of steel pipelines, basic requirements for assessing the effect of corrosion detection and monitoring and other content, internal corrosion control methods. This standard applies to transport oil, steel water pipes and other media, natural gas.