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GB/T 23258-2020 PDF in English

GB/T 23258-2020 (GB/T23258-2020, GBT 23258-2020, GBT23258-2020)
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GB/T 23258-2020: PDF in English (GBT 23258-2020)

GB/T 23258-2020
ICS 75.200
CCS E 98
Replacing GB/T 23258-2009
Standard practice controlling internal corrosion in
steel pipelines and piping systems
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 
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
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
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
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
- 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.
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
Pitting rate
Average corrosion rate
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
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
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
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
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
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
Source: Above contents are excerpted from the PDF -- translated/reviewed by: www.chinesestandard.net / Wayne Zheng et al.