NACE SP0113-2013 Pipeline Integrity Method Selection (Item No 21171).pdf

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1、 Standard Practice Pipeline Integrity Method Selection This NACE International standard represents a consensus of those individual members who have reviewed this document, its scope, and provisions. Its acceptance does not in any respect preclude anyone, whether he or she has adopted the standard or

2、 not, from manufacturing, marketing, purchasing, or using products, processes, or procedures not in conformance with this standard. Nothing contained in this NACE standard is to be construed as granting any right, by implication or otherwise, to manufacture, sell, or use in connection with any metho

3、d, apparatus, or product covered by letters patent, or as indemnifying or protecting anyone against liability for infringement of letters patent. This standard represents minimum requirements and should in no way be interpreted as a restriction on the use of better procedures or materials. Neither i

4、s this standard intended to apply in all cases relating to the subject. Unpredictable circumstances may negate the usefulness of this standard in specific instances. NACE assumes no responsibility for the interpretation or use of this standard by other parties and accepts responsibility for only tho

5、se official NACE interpretations issued by NACE in accordance with its governing procedures and policies which preclude the issuance of interpretations by individual volunteers. Users of this NACE standard are responsible for reviewing appropriate health, safety, environmental, and regulatory docume

6、nts and for determining their applicability in relation to this standard prior to its use. This NACE standard may not necessarily address all potential health and safety problems or environmental hazards associated with the use of materials, equipment, and/or operations detailed or referred to withi

7、n this standard. Users of this NACE standard are also responsible for establishing appropriate health, safety, and environmental protection practices, in consultation with appropriate regulatory authorities if necessary, to achieve compliance with any existing applicable regulatory requirements prio

8、r to the use of this standard. CAUTIONARY NOTICE: NACE standards are subject to periodic review, and may be revised or withdrawn at any time in accordance with NACE technical committee procedures. NACE requires that action be taken to reaffirm, revise, or withdraw this standard no later than five ye

9、ars from the date of initial publication and subsequently from the date of each reaffirmation or revision. The user is cautioned to obtain the latest edition. Purchasers of NACE standards may receive current information on all standards and other NACE publications by contacting the NACE FirstService

10、 Department, 1440 South Creek Dr., Houston, TX 77084-4906 (telephone +1 281-228-6200). Approved 2013-03-16 NACE International 1440 South Creek Drive Houston, Texas 77084-4906 +1 281-228-6200 ISBN 1-57590-259-1 2013, NACE International NACE SP0113-2013 Item No. 21171 SP0113-2013 NACE International i

11、_ Foreword This standard practice provides guidance on determining the appropriate integrity assessment method for diagnosing the corrosion threats recognized as part of a pipeline integrity process. This NACE integrity assessment methodology is limited to addressing external corrosion (EC), interna

12、l corrosion (IC), and stress corrosion cracking (SCC). It has the potential to indicate prior mechanical damage threats, such as third party or vandalism, and it cannot locate threats that are the result of equipment damage, manufacturing technologies, construction practices, incorrect operations, o

13、r weather and external force. The integrity assessment techniques to be covered include in-line inspection (ILI), direct assessment (DA), pressure testing, and other new technology techniques. The pipeline integrity process is a continuous improvement process. A particular assessment integrity metho

14、d may not be the same one used for the first and subsequent assessment. The lessons learned after each assessment assist in determining the appropriate method for subsequent assessments. Through successive applications of the integrity assessment methods, a pipeline operator should be able to identi

15、fy and address locations at which corrosion activity has occurred, is occurring, or may occur. The process is intended to assist in locating areas where defects could form in the future rather than only identifying those areas where defects have already formed. This standard is intended for use by i

16、ndividuals and teams planning, implementing, and managing corrosion integrity assessment projects and programs, including managers, supervisors, and engineers. The integrity assessment process in this standard is specifically intended to address buried onshore pipelines constructed from ferrous mate

17、rials. Users of this standard must be familiar with all applicable pipeline safety regulations and industry standards for the jurisdiction in which the pipeline operates. This includes all regulations requiring specific pipeline integrity assessment practices and programs. This NACE Standard was dev

18、eloped by Task Group (TG) 401, “Integrity Assessment Tool Selection,” which is administered by Specific Technology Group (STG) 35, “Pipelines, Tanks, and Well Casings.” This standard is issued by NACE International under the auspices of STG 35. In NACE standards, the terms shall, must, should, and m

19、ay are used in accordance with the definitions of these terms in the NACE Publications Style Manual. The terms shall and must are used to state a requirement, and are considered mandatory. The term should is used to state something good and is recommended, but is not considered mandatory. The term m

20、ay is used to state something considered optional. _ SP0113-2013 ii NACE International _ NACE International Standard Practice Pipeline Integrity Method Selection Contents 1. General 1 2. Definitions . 2 3. Technology Descriptions . 3 4. First-Time Assessment . 12 5. Subsequent Assessments 15 Referen

21、ces 18 Bibliography . 19 Table 1: Standards and Reports on Assessment Processes . 3 _ SP0113-2013 NACE International 1 _ Section 1: General 1.1 Introduction 1.1.1 Corrosion integrity assessment is a process for improving pipeline safety. Its primary purpose is to prevent future corrosion damage. 1.1

22、.2 For accurate and correct application of this standard, the standard shall be used in its entirety. Using or referring to only specific paragraphs or sections may lead to misinterpretation and misapplication of the recommendations and practices contained herein. 1.1.3 This standard provides the ev

23、aluation methodology, but does not designate practices for every specific or unique situation because of the complexity of conditions to which buried piping systems are exposed. 1.1.4 This standard presents a methodology for the selection of integrity assessment methods for external corrosion, inter

24、nal corrosion, and SCC on onshore ferrous pipelines carrying natural gas and hazardous liquids. 1.1.5 This standard provides flexibility for the pipeline operator to tailor the corrosion integrity assessment method to specific pipeline situations. 1.1.6 This methodology is a continuous improvement p

25、rocess. Through periodic successive assessments, the process should identify and address locations at which corrosion activity has occurred, is occurring, or may occur, and show the effectiveness of various mitigation programs. 1.1.6.1 This methodology provides the advantage and benefit of locating

26、areas in which corrosion wall loss may form in the future rather than only areas in which corrosion defects have already formed. 1.1.6.2 Comparing the results of the successive periodic assessments is one method of evaluating the integrity assessment process, determining the effectiveness, and demon

27、strating that confidence in the integrity of the pipeline with respect to the corrosion threats continuously improving. 1.1.7 The individual integrity assessment processes may detect pipeline integrity threats other than EC, IC, and SCC, such as mechanical damage, microbiologically influenced corros

28、ion (MIC), etc. When such threats are detected, additional assessments and inspections should be performed. The pipeline operator should utilize appropriate assessment methods such as those listed in ANSI(1)/ASME(2) B31.4,1 ANSI/ASME B31.8,2 ANSI/ASME B31.8S,3 and API(3) 11604 to address each of the

29、se other risks. 1.1.8 Each integrity assessement method complements the others. They do not have identical performance, but each has advantages over the others. All pipelines may be successfully assessed with just one particular method. Precautions should be taken when applying these methodologies,

30、just as with other assessment methods, in order to choose what is most appropriate. 1.1.9 The provisions of this standard should be applied under the direction of competent persons who, by reason of knowledge of the physical sciences and the principles of engineering and mathematics, acquired by edu

31、cation and related practical experience, are qualified to engage in the practice of corrosion control and risk assessment on buried ferrous piping systems. Such persons may be registered professional engineers or persons recognized as corrosion specialists or cathodic protection (CP) specialists by

32、organizations such as NACE or engineers or technicians with suitable levels of experience, if their professional activities include external corrosion control of buried ferrous piping systems. (1) American National Standards Institute (ANSI), 25 West 43rd St., 4th Floor, New York, NY 10036. (2) ASME

33、 International (ASME), Three Park Ave., New York, NY 10016-5990. (3) American Petroleum Institute (API), 1220 L St. NW, Washington, DC 20005. SP0113-2013 2 NACE International _ Section 2: Definitions Dent: A local change in piping surface contour caused by an external force such as mechanical impact

34、 or rock impact. Dry Gas Internal Corrosion Direct Assessment: The internal corrosion direct assessment process as defined in this standard applicable to normally dry gas systems. External Corrosion Direct Assessment: A four-step process that combines pre-assessment, indirect inspection, direct exam

35、ination, and post assessment to evaluate the effect of external corrosion on the integrity of a pipeline. Examination: A direct physical inspection touching the exposed profile of a pipeline anomaly by a person, which may include the use of nondestructive examination techniques. Gouge: Elongated gro

36、oves or cavities usually caused by mechanical removal of metal. Hydrostatic Test: A pressure test of a pipeline in which the pipeline is completely filled with water and pressurized to ensure it meets the design strength conditions and is free of leaks. In-Line Inspection: An inspection of a pipelin

37、e from the interior of the pipe using an in-line inspection tool. (also called intelligent or smart pigging) In-Line Inspection Tool: The device or vehicle that uses a nondestructive testing technique to inspect the pipeline from the inside. (also known as intelligent or smart pig) Launcher: A devic

38、e used to insert an in-line inspection tool into a pressurized pipeline. (also known as pig trap or scraper trap) Magnetic Flux Leakage: A type of in-line inspection technology in which a magnetic field is induced in the pipe wall between two poles of a magnet. Anomalies affect the distribution of t

39、he magnetic flux in the wall. The magnetic flux leakage pattern is used to detect and characterize anomalies. Metal Loss: Any pipe anomaly in which metal has been removed. Metal loss is usually the result of corrosion, but gouging, manufacturing defects, or mechanical damaging can also cause wall th

40、inning. Nondestructive Examination: The evaluation of results from x-ray, ultrasonic, or other testing methods or techniques that detect, locate, measure, and evaluate anomalies without sectioning the pipe (see nondestructive testing). Nondestructive Testing: A process that involves the inspection,

41、testing, or evaluation of materials, components, and assemblies for materials discontinuities, properties, and machine problems without further impairing or destroying the parts serviceability. Nondestructive Testing Method: A particular method of nondestructive testing, such as radiography, ultraso

42、nic, magnetic testing, liquid penetrant, visual, leak testing, eddy current, and acoustic emission. Nondestructive Testing Technique: A specific way of utilizing a particular nondestructive testing method that distinguishes it from other ways of applying the same nondestructive testing method. For e

43、xample, magnetic testing is a nondestructive testing method, while magnetic flux leakage and magnetic particle inspection are nondestructive testing techniques. Similarly, ultrasonic is a nondestructive testing method, while contact shear-wave ultrasonic, and contact compression-wave ultrasonic are

44、nondestructive testing techniques. Operator: A person or organization that owns or operates pipeline facilities as an owner or as an agent for an owner. Piggability: A characteristic of a pipeline or pipeline section that has no restrictions for running in-line inspection tools (pigs). Pipeline: A c

45、ontinuous part of a pipe system used to transport a hazardous liquid or gas. A pipeline includes pipe, valves, fittings, and other appurtenances attached to the pipe. SP0113-2013 NACE International 3 Pipeline System: All portions of the physical facilities through which gas, oil, or product moves du

46、ring transportation. This includes pipe, valves, fittings, and other appurtenances attached to the pipe, compressor units, pumping units, metering stations, regulator stations, delivery stations, tanks, holders, and other fabricated assemblies. Pressure: Level of force per unit area exerted on the i

47、nside of a pipe or vessel. Pressure Testing: A method of leak testing in which the component being tested is filled completely with a gas or liquid which is then pressurized. The outside of the component is examined for the detection of any leaks. Receiver: A pipeline facility used for removing a pi

48、g from a pressurized pipeline. It may be referred to as trap, pig trap, or scraper trap. Root-Cause Analysis (from ASME B31.8S): Family of processes implemented to determine the primary cause of an event. These processes all seek to examine a cause-and-effect relationship through the organization and analysis of data. Rupture: The instantaneous tearing or fracturing of pipe material causing large-scale product or water loss. Seam Weld: The longitudinal o