 |
中标分类
行业分类
ICS分类
最新标准
|
登录注册 |
| 您的位置: 标准明细 |
Codeofchina.com is in charge of this English translation. In case of any doubt about the English translation, the Chinese original shall be considered authoritative. This standard is developed in accordance with the rules given in G/T 1.1-2009 Directives for standardization - Part 1: Structure and drafting of standards. This standard replaces SY/T 6597-2014 Specification of in-line inspection for oil and gas pipeline, SY/T 6825-2011 ln-line inspection systems qualification and SY/T 6889-2012 In-line inspection of pipelines. This standard is based on the content of SY/T 6597-2014, and integrates related content of SY/T 6825-2011 and SY/T 6889-2012. In addition to editorial changes, the following main technical changes have been made with respect to SY/T 6597-2014: ——Some terms and definitions are modified and supplemented, which are consistent with the current standards (see Clause 3); ——The “General requirements” is modified and supplemented (see Clause 4); ——The requirements for inspection flow are added (see Clause 5); ——The performance specification requirements of in-line inspection tool are modified and supplemented (see 6.2); ——The requirements for inspection implementation operation plan, marking and tracking, and inspection operation report are added (see Clause 8); ——The requirements for bending strain report and submission time of inspection results are added (see 9.5 and 9.6); ——The requirements for verification of inspection results are modified and supplemented (see Clause 10); ——The requirements for verification of performance specification of inspection tool are added (see Clause 11); ——The requirements for inspection data management are added (see Clause 13); ——The requirements for adaptability of newly-built pipelines are added (see Clause 14); ——The requirements for inspection risk control and emergency disposal are added (see Clause 15); ——The requirements for inspection service provider are added (see Clause 16); ——The types and applicability of the inspection tools are modified (see Annex A); ——The list of performance specifications of inspection tools is added (see Annex B); ——The examples for performance specifications of inspection tools are modified (see Annex C); ——The verification methods and processes of defects are added (see Annex H); ——The examples for verification of performance specifications of inspection tools are added (see Annex I). This standard was proposed by and is under the jurisdiction of the Technical Committee for Standardization of Oil and Gas Storage and Transportation. This standard replaces SY/T 6597-2014, SY/T 6825-2011 and SY/T 6889-2012. The previous edition of SY/T 6597-2014 is as follows: ——SY/T 6597-2004. Specification for in-line inspection of oil & gas pipeline 1 Scope This standard specifies the technical requirements for in-line inspections such as geometry inspection, metal loss inspection, crack inspection and centerline mapping of oil & gas pipelines. This standard is applicable to in-line inspection of onshore steel oil & gas pipelines, and may be referenced for in-line inspection of submarine steel oil & gas pipelines. 2 Normative references The following referenced documents are indispensable for the application of this document. For dated references, only the edition cited applies. For undated references, the latest edition of the referenced document (including any amendments) applies. GB 32167 Oil and gas pipeline integrity management specification SY/T 0087.5 Standard of steel pipeline and tank corrosion assessment - Part 5: Comprehensive analysis of corrosion data for oil and gas pipeline SY/T 5536 Specification for operation of crude oil pipelines SY/T 5922 The operation regulation of gas pipeline 3 Terms and definitions For the purposes of this document, the following terms and definitions apply. 3.1 in-line inspection (ILI) method of inspecting the defects (corrosion, damage, deformation, crack, etc. of the inner and outer walls), centerline position and structural features (welds, tees, bends, etc.) of pipelines with the help of fluid pressure difference 3.2 geometry inspection in-line inspection of pipelines with the main purpose of inspecting the geometric deformation of pipe body 3.3 metal loss inspection in-line inspection of pipelines with the main purpose of inspecting the pipe wall corrosion, gouge and other metal losses 3.4 crack inspection in-line inspection with the main purpose of inspecting cracks in pipe wall 3.5 magnetic flux leakage (MFL) in-line inspection technology that magnetizes the pipe wall with magnets and inspects the defects and pipe features in pipe bodies and welds depending on the change of magnetic flux 3.6 inertial mapping in-line inspection by mapping the spatial position of pipeline centerline using inertial sensor, which can generate pipeline elevation and plan through analysis 3.7 in-line inspection tool equipment or tool for inspecting the defects (corrosion, damage, deformation, crack, etc. of the inner and outer walls), centerline position and structural features (welds, tees, bends, etc.) of pipelines with the help of fluid pressure difference 3.8 gauge plate soft metal disc (usually aluminum disc) with a diameter less than the nominal inner diameter of the pipeline, which is installed on the pig to qualitatively determine the deformation degree of pipeline 3.9 above-ground marker (AGM) portable or permanent equipment placed above the pipeline, which can detect and record the passing signal of the in-line inspection tool, or of which the signal emitted can be detected and recorded by the in-line inspection tool 3.10 marking work of setting ground measurement reference points in order to locate the detected pipeline features accurately and track the operation state of inspection tool in the inspection process 3.11 performance specification a series of technical indexes used to determine the inspection, classification and characterization capabilities of in-line inspection tool 3.12 detection threshold critical value that a certain feature size shall exceed in order to obtain the specified probability of detection 3.13 reporting threshold parameter indicating whether an anomaly shall be reported, which may be a limit value about the depth, width or length of an anomaly or feature 3.14 probability of detection (POD) probability that a feature can be detected 3.15 probability of identification (POI) probability of correctly identifying detected anomalies or other features 3.16 sizing accuracy accuracy of reported anomaly size or characteristics, which is usually expressed in terms of tolerance and certainty. For example, the sizing accuracy of the depth of metal loss may be expressed as a wall thickness with a certainty of 90% and a tolerance of ±10% 3.17 certainty probability that the anomaly feature reported by the test result is within a given tolerance range 3.18 confidence level probability that the overall parameter value falls within a certain interval of the sample statistical value, which is used to describe the certainty of data under specified conditions 3.19 tolerance range used to estimate or characterize the anomaly size or characteristic under a specified certainty 3.20 interaction rules rules of interval between anomalies established when the adjacent anomalies are treated as a single larger anomaly 3.21 feature all physical objects detected by the in-line inspection tool, which may be anomalies, components, adjacent metal objects, welds, appendices, etc. 3.22 characteristic physical description of pipeline (such as grade, wall thickness and manufacturing method) or anomaly (such as type, size and shape) 3.23 anomaly unverified deviations from normal in pipes, coatings or welds 3.24 defect anomaly with size or characteristic exceeding acceptable limit 3.25 imperfection anomaly with size or characteristic not exceeding acceptable limit 3.26 deformation permanent change in shape, such as bending, buckle, dent, ovality, ripple, wrinkle or other changes that affect the roundness or straightness of pipeline section 3.27 dent local elastoplastic deformation in which the curvature of the pipeline surface changes significantly due to impact or extrusion by external force 3.28 ovality degree of deviation of the pipeline cross-section from the normal graph, which is calculated using the formula: ovality (%) = (maximum diameter - minimum diameter) / nominal diameter 3.29 wrinkle smooth and locally convex part of the outer wall of a pipe 3.30 buckle large plastic deformation of the pipeline, resulting in permanent wrinkling or deformation of the whole pipeline or pipeline section 3.31 metal loss any anomaly in pipeline with metal loss, which is usually caused by corrosion, but may also be caused by scratches, manufacturing defects or mechanical flaws 3.32 corrosion deterioration of a material (usually metal) due to chemical or electrochemical reaction with its environment 3.33 pitting metal loss confined to a local area on a metal surface 3.34 gouge elongated groove or cavity caused by mechanical cutting of metal 3.35 crack fractured discontinuity, which is mainly characterized by sharp tips and large length-width ratio at the opening displacements 3.36 stress corrosion cracking (SCC) a kind of crack in material resulting from a combination of tensile stress (residual or applied) and a corrosive environment 3.37 lamination delamination due to internal separation of metals, which is usually parallel to the surface 3.38 cold work permanent strain that accompanies the deformation and hardening of metals 3.39 hard spot local spot with higher hardness through the pipe wall due to local quenching in the hot rolling process of steel plate 3.40 component physical parts of pipeline except pipe body, including but not limited to valves, welds, tees, flanges, fittings, small openings, branch joints, outlets, supports and anchorage, etc. 3.41 seam weld longitudinal weld or spiral weld formed in the pipe welding process 3.42 casing cylinder installed outside the pipeline to protect the pipeline from exterior damage 3.43 sleeve two semi-cylindrical shells covering the outside of the pipeline and connected together by welding, etc. to repair pipeline defects 3.44 estimated repair factor (ERF) ratio of the maximum allowable operating pressure to the safe operating pressure calculated by the metal loss defect evaluation method ERF=MAOP/psafe where, MAOP——the maximum allowable operating pressure; psafe——the safe operating pressure calculated by metal loss defect evaluation method. 4 General requirements 4.1 Appropriate in-line inspection technology and equipment shall be selected according to the results of pipeline risk assessment and the historical inspection conditions. 4.2 In case of the first application of in-line inspection technology and new equipment or inspection of new defect types, inspection performance verification shall be carried out, which may be performed via traction test or excavation measurement of inspection results. 4.3 The time interval of in-line inspection shall comply with the requirements of GB 32167. 4.4 Pigging operation shall be carried out regularly to keep the pipeline detectable. Pipelines shall be subjected to pigging before in-line inspection. 4.5 The measurement, storage and use of pipeline position data shall comply with national laws and regulations and the confidentiality requirements of pipeline operators. 5 Inspection flow Prior to the start of inspection, an appropriate in-line inspection flow shall be established. In-line inspection may be carried out according to the recommended implementation flow in Figure 1. Figure 1 Implementation flow for in-line inspection of pipeline 6 Selection of inspection technology and equipment 6.1 Considerations in inspection tool selection The purpose and target of the inspection should be determined based on the hazard factors, historical inspection conditions and risk assessment results of pipelines, and the inspection capabilities and performance specifications of the in-line inspection technology and equipment selected shall adapt to the requirements of pipeline inspection. See Annex A for the types and functions of common in-line inspection tools. When selecting the in-line inspection tools, the factors that shall be considered include but are not limited to: a) probability of detection (POD); b) detection threshold; c) type identification capability; d) dimensional sizing accuracy; c) feature positioning accuracy; f) confidence level; g) sampling frequency or spacing of sensor; h) range of wall thickness; i) speed range; j) temperature range; k) pressure range; l) the minimum curvature radius of the bend that can be passed through; m) the minimum inner diameter of the pipeline that can be passed through; n) the length, weight and number of sections of the inspection tool; o) the pressure difference required to launch and operate the inspection tool; p) the length of the pipeline that can be inspected in a single operation (co-determined by operating time, pipeline conditions, etc.) q) size and operating space of pig receiver and launcher; r) the minimum distance between the valve and the reducer of the pig receiver and launcher; s) battery type and life; t) discharge indication when the inspection tool is jammed. 6.2 Performance specification requirements of inspection tool 6.2.1 The performance specification of in-line inspection tool shall specify the ability to detect, locate, identify, characterize and quantify pipeline anomalies and features, including but not limited to the types of anomalies or features, detection threshold and probability of detection (POD), probability of identification (POI), sizing accuracy, positioning accuracy and various restrictions. Specific indexes shall comply with Annex B. 6.2.2 The inspection service provider shall establish the performance specification of in-line inspection tool during operation in specific pipeline by effective statistical methods. See Annex C for the performance specifications of different types of in-line inspection tools. 6.2.3 The performance specification for geometry inspection shall meet the following requirements: a) the POI of dent, ovality, wrinkle, buckle, bulge and weld shall be greater than 90%. b) the POI of valve, tee, bend, change of wall thickness and other features shall be greater than 98%. c) the dimensional sizing accuracy of geometry inspection shall meet the requirements of Table 1, and the feature positioning accuracy shall meet the requirements of Table 2. 6.2.4 The performance specification for magnetic flux leakage inspection shall meet the following requirements: a) the POI of inner/outer metal loss, dent, eccentric casing, component and weld shall be greater than 90%. b) the POI of valve, tee, bend, change of wall thickness and other features shall be greater than 98%. c) the inspection tool shall have the ability to identify and classify the weld anomalies. Table 1 Dimensional sizing accuracy of geometry inspection Detection threshold when POD=90% Accuracy when certainty =90% OD ≤ 406mm 406mm < OD < 1,016mm OD ≥ 1,016mm Change of wall thickness 1.5mm ±1mm Ovality 1% ±1% Dent depth 1%OD ±2mm ±3.5mm ±5mm Note: OD is the outer diameter of pipeline. Ovality (%) = (maximum diameter - minimum diameter) / nominal diameter. Table 2 Feature positioning accuracy of geometry inspection Axial positioning accuracy when certainty =90% The distance error between feature and reference girth weld is less than ±0.1m The distance error between reference girth weld and reference point is less than ±1% Circumferential positioning accuracy when certainty =90% ±15° d) the inspection tool shall have the ability to identify the failure of joint coating where signs of corrosion have occurred. e) the dimensional sizing accuracy of metal loss inspection shall meet the requirements of Table 3, and the feature positioning accuracy shall meet the requirements of Table 4. Table 3 Dimensional sizing accuracy of metal loss inspection General metal loss (4A×4A) Pitting (2A×2A) Axial groove Circumferential groove Seamless steel pipe Longitudinal (spiral) welded steel pipe Seamless steel pipe Longitudinal (spiral) welded steel pipe Seamless steel pipe Longitudinal (spiral) welded steel pipe Seamless steel pipe Longitudinal (spiral) welded steel pipe Detection threshold when POD=90% 9%WT 5%WT 13%WT 8%WT 13%WT 8%WT 9%WT 5%WT Depth accuracy when certainty = 90% ±10%WT ±10%WT ±10%WT ±10%WT -15%/+10%WT -15%/+10%WT -10%/+15%WT -10%/+15%WT Width accuracy when certainty = 90% ±15mm ±15mm ±15mm ±15mm ±15mm ±15mm ±15mm ±15mm Length accuracy when certainty = 90% ±10mm ±10mm ±10mm ±10mm ±10mm ±10mm ±10mm ±10mm Note: WT is the wall thickness of steel pipe, and see Annex D for the definition of A. Table 4 Feature positioning accuracy of magnetic flux leakage inspection Axial positioning accuracy when certainty =90% The distance error between feature and reference girth weld is less than ±0.1m The distance error between reference girth weld and reference point is less than ±1% Circumferential positioning accuracy when certainty =90% ±5° 6.2.5 The performance specification for WM inspection shall meet the following requirements: a) the POI of inner/outer metal loss, interlayer, component and weld shall be greater than 90%. b) the POI of valve, tee, bend, change of wall thickness and other features shall be greater than 98%. c) the dimensional sizing accuracy of metal loss inspection shall meet the requirements of Table 5, and the feature positioning accuracy shall meet the requirements of Table 6. Table 5 Dimensional sizing accuracy of metal loss inspection Certainty Pitting with diameter ≥10mm Pitting with diameter ≥20min General metal loss Axial groove Circumferential groove lamination related to manufacturing or caused by hydrogen induced crack Detection threshold when POD=90% 1.5mm 1mm 1mm 1mm 1mm 1mm Depth measurement accuracy 80% Detectable ±0.4mm ±0.4mm ±0.4mm ±0.4mm ±0.4nmm 90% ±0.5mm ±0.5mm ±0.5mm ±0.5mm ±0.5mm Width measurement accuracy 80% ±10mm ±10mm ±10mm ±10mm ±10mm ±10mm 90% ±12mm ±12mm ±12mm ±12mm ±12mm ±12mm Length measurement accuracy 80% ±5mm ±5mm ±5mm or ±5% of length ±5mm or ±5% of length ±5mm ±5mm or ±5% of length 90% ±6mm ±6mm ±6mm or ±6% of length ±6mm or ±6% of length ±6mm ±6mm or ±6% of length Table 6 Feature positioning accuracy of WM inspection Axial positioning accuracy when certainty =90% The distance error between feature and reference girth weld is less than ±0.1m The distance error between reference girth weld and reference point is less than ±1% Circumferential positioning accuracy when certainty =90% ±5° 6.2.6 The performance specification for CD inspection shall meet the following requirements: a) for cracks with a length greater than 25mm, the ones with a depth greater than 1mm in the base metal or the ones with a depth greater than 2mm in the weld, the POD shall be greater than 90%. b) the dimensional sizing accuracy of crack inspection shall meet the requirements of Table 7, and the feature positioning accuracy shall meet the requirements of Table 8. Table 7 Dimensional sizing accuracy of crack inspection Certainty Measurement accuracy Depth 90% With depth classification: < 12.5%WT (12.5%-25%) WT (25%~40%) WT > 40%WT Length 90% ±10%WT (feature length >100mm) ±10mm (feature length ≤100mm) Width 90% ±50mm for crack cluster Table 8 Feature positioning accuracy of CD inspection Circumferential positioning accuracy when certainty =90% The distance error between feature and reference girth weld is less than ±0.1m The distance error between reference girth weld and reference point is less than ±1% Axial positioning accuracy when certainty =90% ±5° 6.2.7 The performance specification for inertial mapping shall meet the following requirements: a) if the distance between ground reference points is less than 1km, the positioning deviation shall not be greater than ±1m. b) a single inspection shall identify the bending deformation feature with a curvature radius of less than 400D (D is pipe diameter), and repeated inspections shall identify the bending deformation feature with a curvature radius of less than 2,500D. 6.3 Evaluation of pipeline inspection conditions 6.3.1 Pipeline operator and inspection service provider should jointly collect relevant information of pipelines to be inspected, evaluate the suitability of pipeline inspection, and update and reform the restrictions affecting pipeline inspection. 6.3.2 The pipeline operator shall provide the inspection service provider with a pipeline questionnaire (see Annex E for an example of the questionnaire), which lists the physical features and operating conditions of the pipeline to be inspected, so that the inspection service provider can evaluate whether the pipeline conditions meet the operation condition of the inspection tool, and the evaluation shall at least include the following contents: a) receiving and launching conditions, including but not limited to: 1) size of pig receiver and launcher: the inspection service provider shall evaluate the applicability of the size of the pig receiver and launcher. 2) operating space: there shall be sufficient operating space for in-line inspection tool during receiving and launching. b) tee, including but not limited to: 1) whether there is a tee without blocking strip or baffle. 2) center distance of adjacent tees. c) bend, including but not limited to: 1) the minimum curvature radius of the bend existing on the pipeline. 2) length of straight pipe section between adjacent bends. 3) mitre bend and its mitre angle. 4) continuous bend. d) valve, including but not limited to: 1) valve type and inner diameter of valve cavity. 2) if there is a check valve, ensure that it can be locked in the fully open position when the pig or inspection tool is operating. e) pipeline materials, including but not limited to: 1) steel grade and pipe type. 2) distribution and range of pipe wall thickness. f) operation conditions, including but not limited to: 1) medium type: the medium type affects the selection of inspection technology. 2) medium composition: corrosive medium may damage the inspection tool. 3) medium flow rate: it affects the operation speed of the inspection tool, total time and accuracy of inspection. When the medium flow rate does not meet the conditions, it may be considered to adjust the throughput or enable the speed adjustment function of the inspection tool. 4) medium temperature: the medium temperature shall not exceed the temperature range that the inspection tool can bear during operation. 5) operating pressure: most inspection tools have applicable pressure range, too low operating pressure or too low pressure difference in front and at the back of the inspection tool will lead to insufficient driving force of the inspection tool, and too high operating pressure exceeding the pressure resistance design will lead to failure of the in-line inspection tool. g) other restrictions, including but not limited to: 1) inner coating of pipeline. 2) pipe cleanliness. 3) inner diameter change of the pipeline. 4) probe implanted into pipeline. 5) large drop of pipeline and crossing pipe bridge. 6) mechanical support of pipeline and off-design crossing. 7) hydrates and spontaneously combustible substances in the pipeline. 6.3.3 The pipeline operator shall provide pipeline construction related to inspection, maintenance information and historical inspection results. 6.3.4 The inspection service provider shall preliminarily evaluate the detectability of the pipeline according to the information of the pipeline questionnaire. 6.3.5 The inspection service provider shall, with the cooperation of the pipeline operator, conduct site survey and final evaluation of the contents in the pipeline questionnaire. 6.3.6 The pipeline operator shall transform or replace the pipeline and its ancillary facilities that do not meet the operation conditions of the inspection tool. 6.4 Verification of performance specification of inspection tool After the inspection tool is selected, the performance specification of the inspection tool shall be verified. See Clause 1 for specific requirements for verification. 7 Inspection scheme The inspection scheme shall be prepared according to the actual situation and approved by the pipeline operator, and the scheme shall at least include the following contents: a) basic situation of pipeline. b) evaluation on operation conditions and operation process requirements. c) site survey result and risk analysis, special protective measures shall be formulated when the sulfur-containing pipeline receives the inspection tool. d) inspection organization and inspection procedure. e) requirements for inspection tracking, marking and ground measurement (if portable ground tracker is used to track the inspection tool, site survey shall be carried out for whole-line marking points in advance, of which the interval shall not exceed 1km, and it may be added and set in special sections where large rivers cross). f) inspection schedule. g) pigging scheme. h) operation scheme of inspection tool. i) data downloading requirements. j) acceptance criteria of inspection results. k) excavation verification requirements. l) HSE operation requirements. m) emergency response plan. 8 Inspection implementation 8.1 Operation plan The pipeline operator and the inspection service provider should jointly determine the in-line inspection plan, focusing on the following factors: a) inspection implementation time. b) operation process conditions. c) human and material resources. d) Site condition. e) health, safety and environmental factors. 8.2 Marking and tracking 8.2.1 Selection of reference point 8.2.1.1 Ground pipe locater shall be used to patrol the line and select the reference point in the pigging and inspection operations. 8.2.1.2 The reference points should be located with easy access and certain intervals (usually no more than 1km) near the permanent marks such as pipeline mileage posts. 8.2.1.3 Reference points should be added and set at large drop or valve chamber, crossing, turning and other special positions. 8.2.2 Measurement of reference point position 8.2.2.1 The reference point position shall be measured, recorded and maintained as part of the permanent data of the pipeline. 8.2.2.2 It should be installed at the reference point just above the pipeline with permanent magnet as a permanent mark. 8.2.3 Tracking and monitoring 8.2.3.1 Before the start of tracking, the reference points shall be listed, and a tracking plan shall be made in advance according to the position and quantity of reference points. 8.2.3.2 The inspection service provider shall provide a corresponding number of above-ground markers according to needs of the site, and ensure that each marker functions normally. 8.2.3.3 The inspection service provider shall train the tracking personnel in the use of above-ground markers in advance, and ensure that all tracking personnel can operate correctly. 8.2.3.4 Before pigging and inspection, the tracking personnel shall patrol the marking points of the whole line in advance, set the tracking entry route, and organize simulated tracking if necessary. 8.2.3.5 After the inspection tool is launched, the tracking personnel hold the above-ground marker to track according to the preset reference point. When the inspection pipeline is long, the tracking can be carried out in an alternating way. In areas difficult for personnel and vehicles to enter, the tracking marker can be buried in advance at the reference point. 8.2.3.6 When the inspection tool passes through important reference points such as valve chamber and crossing, the tracking personnel shall report the operation state in time. 8.2.3.7 In case of special circumstances, the tracking personnel shall immediately report to the dispatcher. If it is found that more than three consecutive above-ground markers are not triggered when tracking, and the pig/inspection tool cannot be found to pass through via vibration, the corresponding emergency response plan shall be started to find the specific position of the inspection tool or pig in time. 8.3 Pigging 8.3.1 Pigging shall be carried out before in-line inspection, and in-line inspection pigging is generally divided into two stages, the first stage is gauge pigging and the second stage is enhanced pigging. 8.3.2 The pigging operation flow shall be implemented according to Annex F and meet the requirements of SY/T 5536 or SY/T 5922. 8.3.3 When selecting pigs, the materials, pigging capacity and interference of different types of pigs shall be considered. 8.3.4 The pig shall be equipped with tracking instruments. The pig tracking scheme shall be set and tracking and monitoring shall be organized according to the production requirements. 8.3.5 During the gauge pigging stage, pigs with passability not lower than that used for routine maintenance can be used for pigging, and the pipeline passability can be judged by installing gauge plate. The gauge plate should be aluminum round plate, and the diameter shall not be less than the minimum passing diameter of the inspection tool. If the gauge plate is damaged, the cause of the damage shall be analyzed in time. If it is determined through analysis that the damage is caused by large deformation of the pipeline, the inspection service provider shall evaluate whether the deformation of the pipeline meets the passing conditions of the inspection tool. If the inspection tool can't pass and can't locate the accurate position of the deformation point after evaluation, geometry inspection shall be carried out. 8.3.6 Straight plate, steel brush, magnetic force and other pigs are used for pigging at the enhanced pigging stage until the requirements of in-line inspection are met, and following requirements shall be met: a) before the inspection tool is put into operation in the pipeline without inner coating, the steel brush and magnetic pig should be operated at least once, and in the pipeline with inner coating, the appropriate pig shall be selected according to the situation. b) the weight of debris removed is less than 5kg, or the weights of debris removed by two consecutive times of pigging are equivalent and meet the inspection requirements. 8.3.7 When it is possible to remove FeS or other spontaneously combustible substances, protective measures such as water injection and spraying shall be taken for the pig receiver before opening the blind plate. 8.4 Operation of inspection tool 8.4.1 Launching of inspection tool 8.4.1.1 The inspection tool shall be commissioned before launching to ensure the normal operation of each system. 8.4.1.2 The transmitting and tracking device shall be inspected to ensure its integrity before inspection tool launching. 8.4.1.3 Refer to Annex F for the launching process of the inspection tool which shall comply with the relevant operation procedures for pipeline operation. 8.4.1.4 During the operation of the inspection tool, it shall be tracked and monitored according to the provisions of 8.2.3. 8.4.2 Receiving of inspection tool 8.4.2.1 Refer to Annex F for the receiving process of the inspection tool which shall comply with the relevant operation procedures for pipeline operation. 8.4.2.2 When it is possible to remove FeS or other spontaneously combustible substances, protective measures such as water injection and spraying shall be taken for the pig receiver before opening the blind plate. 8.4.2.3 After the inspection tool is taken out of the pig receiver, it shall be visually inspected and cleaned. 8.4.2.4 Download and back up inspection data 8.4.2.5 The integrity of data shall be inspected, including: a) whether the signals of each channel are clear and complete. b) whether the data of the above-ground marker is complete. c) evaluating whether data integrity is acceptable. 8.4.3 Inspection operation report The inspection operation report shall be submitted after the inspection is completed, which should include the following contents: a) name of pipeline. b) operation date. c) type of inspection tool. d) pipeline diameter and operation distance. e) all important changes made to the inspection tool. f) operation average speed and speed curve. g) success or failure of the operation, and analysis of the failure causes and re-operation measures if it fails. 9 Submission of inspection results 9.1 General requirements 9.1.1 The pipeline operator and the inspection service provider shall agree on the requirements for submitting the inspection results in advance. If the inspection items adopt multiple inspection technologies (such as magnetic flux leakage and ultrasonic inspection tool) or multiple functions are combined on one inspection tool (such as magnetic flux leakage and inertial mapping combined inspection tool), the pipeline information obtained by different types of inspection tools shall be aligned and combined in the same report and the same anomaly (defect) list. See Annex G for specific requirements for the inspection report. 9.1.2 The inspection service provider shall provide the electronic inspection report, which shall include the following information: a) overview of inspection works, including pipeline defects b) performance specification of inspection tool c) inspection time d) operation data of inspection tool e) list of pipeline features f) anomaly list g) statistical data and summary h) ERF and defect evaluation method i) excavation list of severe defect points j) correspondence between ground reference points and relatively permanent marks on pipelines (such as inspection post, etc.) 9.1.3 The following operation data of inspection tool shall be given in the report, and each inspection tool shall be described separately: a) data sampling frequency or spacing b) detection threshold c) report threshold, if both parties do not specify, use the feature when POD=90% d) operation speed curve, pressure curve and temperature curve of the inspection tool e) statistics of damaged sensors f) echo loss statistics if ultrasonic inspection tool is used 9.1.4 The anomaly feature list file shall be provided, and the hard disk copy of the inspection data and the customer management software shall be provided. The functions that the software shall have include but are not limited to: a) showing the initial data. b) showing the absolute distance and relative distance of the feature. c) showing the clock orientation of the feature. d) measuring the axial distance and circumferential distance of any two points on the pipeline e) generating the clock orientation of the intersection of spiral weld (longitudinal weld) and girth weld. f) generating the excavation list g) quickly positioning and inquiring based on girth weld number or inspection mileage. 9.2 Requirements for geometry inspection report The classification statistical results of geometric deformation shall be given in the form of data and statistical graph, and the specific contents are as follows: a) statistical data shall include: 1) the quantity of all geometric deformation points; 2) the quantity of all dents; 3) dent quantity with 1%OD≤depth<6%OD; 4) dent quantity with 6%OD≤depth<9%OD; 5) dent quantity with depth≥9%OD; 6) quantity of total ovality; 7) ovality quantity with 1%OD≤deformation amount<5%OD; 8) ovality quantity with 5%OD≤deformation amount<10%OD; 9) ovality quantity with deformation amount≥10%OD; 10) quantity of all bulges; 11) quantity of all wrinkles; 12) quantity of all buckles; b) statistical graph shall include: 1) distribution diagram of all deformation points along pipeline mileage; 2) clock orientation distribution diagram of all dents along pipeline mileage. Foreword III 1 Scope 2 Normative references 3 Terms and definitions 4 General requirements 5 Inspection flow 6 Selection of inspection technology and equipment 6.1 Considerations in inspection tool selection 6.2 Performance specification requirements of inspection tool 6.3 Evaluation of pipeline inspection conditions 6.4 Verification of performance specification of inspection tool 7 Inspection scheme 8 Inspection implementation 8.1 Operation plan 8.2 Marking and tracking 8.3 Pigging 8.4 Operation of inspection tool 9 Submission of inspection results 9.1 General requirements 9.2 Requirements for geometry inspection report 9.3 Requirements for metal loss inspection report 9.4 Requirements for centerline mapping report 9.5 Requirements for bending strain report 9.6 Requirements for submission time 10 Verification of inspection results 10.1 General requirements 10.2 Measurement methods of defects 10.3 Verification report 11 Verification of performance specification of inspection tool 11.1 General requirements 11.2 Based on historical data 11.3 Based on the traction test 11.4 Based on excavation verification 11.5 Single-point verification measurement 11.6 Inspection for performance specification based on statistics 12 Project completion data 13 Inspection data management 13.1 Inspection data 13.2 Inspection information 13.3 Comparison of inspection data and use of corrosion growth rate 14 Requirements for adaptability of newly-built pipelines 15 Inspection risk control and emergency disposal 15.1 General requirements 15.2 Preventive measures 15.3 Emergency disposal 16 Requirements of inspection service provider 16.1 General requirements 16.2 Requirements for operating personnel’s capability 16.3 Requirements for data analysis personnel’s capability Annex A (Informative) Types and functions of inspection tools Annex B (Normative) List of performance specifications of inspection tools Annex C (Informative) Examples for performance specifications of inspection tools Annex D (Normative) Definition of metal loss types Annex E (Informative) Example of pipeline questionnaire Annex F (Normative) Work flow of pig receiving and launching Annex G (Informative) Example of inspection report Annex H (Informative) Verification methods and processes of defects Annex I (Informative) Examples for verification of performance specifications of inspection tools 油气管道内检测技术规范 1 范围 本标准规定了油气管道几何变形、金属损失，裂纹和中心线测绘内检测的技术要求。本标准适用于陆上钢质油气管道内检测。海底钢质油气管道内检测可参照执行。 2 规范性引用文件 下列文件对于本文件的应用是必不可少的。凡是注日期的引用文件，仅注日期的版本适用于本文件。凡是不注日期的引用文件，其最新版本（包括所有的修改单）适用于本文件。 GB 32167 油气输送管道完整性管理规范 SY/T 0087.5 钢质管道及储罐腐蚀评价标准 第5部分：油气管道腐蚀数据综合分析SY/T 5536 原油管道运行规程 SY/T 5922 天然气管道运行规范 3 术语和定义 下列术语和定义适用于本文件。 3.1 内检测 in-line inspection (ILI) 借助于流体压差使检测器在管内运动，检测管道缺陷（内外壁腐蚀、损伤、变形、裂纹等)、中心线位置和结构特征(焊缝、三通、弯头等)的方法。 3.2 几何变形检测 geometry inspection 以检测管体几何变形情况为主要目的的管道内检测。 3.3 金属损失检测 metal loss inspection 以检测管壁腐蚀，划痕等全属损失为主要目的的管道内检测。 3.4 裂紋检测 crack inspection 以检测管壁裂纹为主要目的的内检测。 3.5 漏磁检测 magnetic flus leakage (MFL) 利用磁铁磁化管壁，通过磁通量变化，检测管体和.缝中存在的缺陷和管道特征的内检测技术。 3.6 惯性测绘检测 inertial mapping 使用惯性传感器测绘管道中心线空间位置的内检测，通过分析可生成管道高程和平面图。 3.7 内检测器 in-line inspection tool 借助于流体压差使检测器在管内运动，检测管道缺陷(内外壁腐蚀，损伤、变形、裂纹等)，中心线位置和结构特征（焊缝、三通、弯头等)的设备或工具。 3.8 测径板 gauge plate 安装在清管器上，直径小于管道公称内径的软质金属圆盘（通常使用铝盘)。用于定性判定管道的变形程度。 3.9 标识器 above-ground marker (AGM) 置于管道上方的便携或永久性设备，能够探测并记录内检测器的通过信号，或内检测器能够探测并记录其发射的信号。 3.10 设标 marking 为实现对检测到的管道特征精确定位和检测过程中对检测器运行状况进行跟踪而设置地面测量参考点的工作。 3.11 性能规格 performance specification 用于确定内检测器检测、分类，表征特征能力的一系列技术指标。 3.12 检测國值 detection threshold 为获得指定的检测概率，某一特征尺寸应超出的临界值。 3.13 报告國值 reporting threshold 说明是否应报告某一异常的参数。该参数可以是一个有关异常或特征的深度、宽度或长度的限制值。 3.14 检测概率 probability of detection (POD) 特征能被检测出来的概率。 3.15 识别概率 probability of identification (POI) 能够正确识别被检测到的异常或其他特征的概率。 3.16 量化精度sizing accuracy 报告的异常尺寸或特性的精度。通常精度用公差和可信度表示。如金属损失的深度量化精度可表示为可信度为90%时，公差为士10%的壁厚。 3.17 可信度 certainty 检测结果报告的异常特征在给定公差范围内的概率。 3.18 置信度 confidence level 总体多数谊落在样本统计值某一区间的概率，用于描述在指定条件下数据的可信度。 3.19 公差 tolerance 在指定可信度下，估算或表征异常尺寸或特征的范图。 3.20 交互作用准则 interaction rules 将相邻异常按单个较大的异常处理时，制定的异常之间的间隔准则。 3.21 特征 feature 内检测器检测到的所有物理对象。特征可能是异常、部件、邻近金属物、焊缝、附属物等。 3.22 特征 characteristic 管道（例如等级、壁厚和制造方法）或异常(例如类型、尺寸和形状)的物理描述。 3.23 异常 anomaly 管材、涂层或焊缝等存在的偏离正常的未经验证的偏差。 3.24 缺陷 defect 尺寸或特性超出可接受限度的异常。 3.25 缺欠 imperfection 尺寸或特性未超出可接受限度的异常。 3.26 变形 deforreation 形状的永久性改变，如弯曲、屈曲、凹陷、椭圆度、波纹、褶皱或影响管道截面圆度或平直度的其他变化， 3.27 凹陷 dent 因外力撞击或挤压造成管道表面曲率明显变化的局部弹塑性变形。 3.28 棚圆度 ovality 管道横截面偏离正常图形的程度，其计算公式为：椭圆度(%)=(最大直径-最小直径)/公称直径。 3.29 褶皱 wrinkle 管子外壁光滑而局部凸起的部分。 3.30 屈曲 buckle 管道产生较大的塑性变形，造成管道整体或管道截面永久性起皱或变形。 3.31 金属损失 metal loss 任何发生金属减损的管道异常。金属损失通常是由于腐蚀所致，但划伤、制造缺陷或机械损伤也能导致金属损失。 3.32 腐蚀 corrosion 由于与所处环境发生化学或电化学反应，造成某种材料(通常是金属)的劣化。 3.33 点蚀 pitting 金属表面局限于局部小区城的金属损失。 3.34 划痕 gouge 金属机械切削造成的细长凹槽或凹腔。 3.35 裂纹 crack 一种断裂型不连续，其主要特征为锋利的尖端和张开位移处长宽比大。 3.36 应力腐蚀开裂 stress corrosion cracking (SCC) 材料由于拉伸应力（残余或外加的)与腐蚀环境综合作用产生的一种裂纹。 3.37 分层 lamination 由于金属内部分离形成的通常平行于表面的离层。 3.38 冷作 cold work 金属由于变形硬化伴随的永久应变。 3.39 硬点 hard spot 在钢板热轧过程中，由于局部淬火产生的贯通管壁的局部硬度增加。 3.40 部件 component 管道线路上除管体以外的物理部分，包括但不限于阙门、焊缝、三通、法兰、配件、小开口、分支接头、出口、支撑和锚固等。 3.41 制管焊缝 seam weld 焊管制造过程中形成的直焊缝或螺旋焊缝。 3.42 套管 casing 安装在管道外的圆筒，用于保护管道不受外部损伤。 3.43 套筒 sleeve 覆盖在管道外，通过焊接等方式连接在一起，用于修复管道缺陷的两个半圆柱外壳， 3.44 估计维修因子 estimated repair factor (ERF) 最大允许运行压力与通过金属损失缺陷评价方法计算出的安全运行压力的比值。 ERF=MAOP/psafe 式中： MAOP——最大允许运行压力； psafe——通过金属损失缺陷评价方法计算出的安全运行压力。 4 一般要求 4.1 应根据管道风险评估结果及历史检测情况，选择合适的内检测技术及设备。 4.2 首次应用的内检测技术、新设备或检测新的缺陷类型应进行检测性能验证，可通过牵拉试验或检测结果开挖测量进行验证。 4.3 内检测时间间隔应符合GB32167的规定。 4.4 应定期进行清管作业，保持管道的可检测性。管道内检测前应进行清管。 4.5 管道位置数据的馮量、存储及使用等应符合国家法律法规和管道运营方的保密要求。 5 检测流程 检测开始前，应制定合适的内检测流程。内检测可按图1中推荐的实施流程进行。 图1 管道内检测实施流程 选择内检测技术及设备(基于风险评价)、 不合格 检测器性能检测 合格 清槽/测径 跟踪监听 评估测径结果 运行变形检测器定位消除限制点 是 存在检测点 运行限制点 否 验证清管结果 满足要求 否 继续清管 是 运行内检测器 跟踪监听 评估运行结果 失败 分析失败原因 成功检测结果验证 分析检测数据 提交检测报告 满足要求 是 接受检测结果 否再次分析检测数据 提交检测报告 6 检测技术及设备选择 6.1 检测器选择应考虑的因素 宜根据管道存在的危害因素、历史检测情况及风险评估结果确定检测的目的和目标，并使选择的内检测技术及设备的检测能力和性能规格与管道检测的需求相适应。常见内检测器类型与检测用途参见附录A. 选择内检测器时，应考虑的因素包括但不限于； a)检测概率（POD)， b)检测阔值， c)类型识别能力； d)尺寸量化精度， c)特征定位精度； f)置信度： g)传感器采样频率或采样间距； h）壁厚范围； i) 速度范围； j）温度范围； k）压力范围； 1)可通过的弯头的最小曲率半径； m）可通过的最小内径， n）检测器长度、重量和节数； o)发送和运行检测器所需的压差； p)单次运行所能检测的管道长度(由运行时间和管道条件等共同决定)， q)收、发球筒的尺寸和操作空间； r)收，发球筒阀门和大小头（异径管）之间的最小距离， s)电池类型及电池寿命； t)检测器发生卡停时泄流指示。 6.2 检测器性能规格要求 6.2.1 内检测器性能规格应规定探测、定位、识别、表征和量化管道异常和特征的能力，包括但不限于异常或特征的类型、检测读值和检测概率（POD）、识别概率（POI）、量化精度、定位精度以及各种限制，具体指标按附录B执行。 6.2.2 检测服务方应通过有效的统计方法建立内检测器在特定管道运行时的性能规格，不同类型内检测器性能规格参见附录C。 6.2.3 几何变形检测的性能规格应满足： a)凹陷、椭圆度、褶皱、屈曲、鼓胀和焊缝的POI大于90%。 b)阀门，三通、弯头、壁厚变化等特征的POI大于98%。 c）几何变形尺寸量化精度满足表1的要求，特征定位精度满足表2的要求。 6.2.4 漏磁检测的性能规格应满足； a)内/外金属损失、凹陷、偏心套管、部件和焊缝的POI大于90%。 b)阀门、三通、弯头、壁厚变化等特征的POI大于98%。 c）具备识别焊缝异常并对焊缝异常进行分级的能力。 表1 几何变形尺寸量化精度 POD=90%时的 检测阈值 可信度=90%时的精度 OD ≤ 406mm 406mm < OD < 1016mm OD ≥ 1016mm 壁厚变化 1.5mm 土1mm 椭圆度 土1% 土1% 凹陷深度 1%0D ±2mm ±3.5mm ±5mm 注：OD为管道外径， 椭圆度（%）=（最大直径-最小直径)/公称直径。 表2 几何变形检测特征定位精度 可信度=90%时的轴向定位精度 特征与参考环焊缝之间的距离误差小于 ±0.1m 参考环焊缝与参考点之间的距离误差小于±1% 可信度=90%时的环向定位精度 ±15° d)具备识别已发生腐蚀迹象的补口失效能力。 e）金属损失尺寸量化精度满足表3的要求，特征定位精度满足表4的要求。 表3 金属损失尺寸量化精度 普通金属损失(4A×4A) 点蚀 （2A×2A) 轴向沟槽 环向沟槽 无缝 钢管 直（螺旋） 焊缝钢管 无缝 钢管 直（螺旋） 焊缝钢管 无缝 钢管 直（螺旋) 焊缝钢管 无缝 钢管 直（螺旋) 焊缝钢管 POD=90%时的 检测阈值 9%WT 5%WT I3%WT 8%WT 13%WT 8%WT 9%WT 5%WT 可信度=90%时的深度精度 ±10%WT ±10%WT ±10%WT ±10%WT -15%/±10%WT -15%/±10%WT -10%/±15%WT -10%/±15%WT 可信度=90%时的宽度精度 ±15mm ±15mm ±15mm ±15mm ±15mm ±15mm ±15mm ±15mm 可信度=90%时的长度精度 ±10mm ±10mm ±10mm ±10mm ±10mm ±10mm ±10mm ±10mm 注.WT为钢管壁厚，A的定义见附录D 表4 漏磁检测特征定位精度 可信度=90%时的轴向定位精度 特征与参考环焊缝之间的距离误差小于±0.Lm 参考环焊缝与参考点之间的距离误差小于±1% 可信度=90%时的环向定位精度 ±5° 6.2.5 超声测厚检测的性能规格应满足： a)内/外金属损失，夹层、部件和焊缝的POI大于90%。 b)阀门，三通、弯头、壁厚变化等特征的POI大于98%。 c)金属损失尺寸量化精度满足表5的要求，特征定位精度满足表6的要求。 表5 金属损失尺寸量化精度 可信度 直径>10mm的点蚀 直径>20min的点蚀 普通金属损失 轴向沟槽 环向沟槽 制造相关或由氢致裂纹造成的分层 POD=90%时的检测阈值 1.5mm 1mm 1mm 1mm 1mm 1mm 深度测量精度 80% 可探测 ±0.4mm ±0.4mm ±0.4mm ±0.4mm ±0.4nmm 90% ±0.5mm ±0.5mm ±0.5mm ±0.5mm ±0.5mm 宽度测量精度 80% ±10mm ±10mm ＝10mm ±10mm ±10mm ±10mm 90% ±12mm ±12mm ±12mm ±12mm ±12mm ±12mm 长度测量精度 80% ±5mm ±5mm ±5mm或±5%长度 ±5mm或±5%长度 ±5mm ±5mm或±5%长度 90% ±6mm ±6mm ±6mm或±6%长度 ±6mm或±6%长度 ±6mm ±6mm或±6%长度 表6 超声测厚检测特征定位精度 可信度=90%时的轴向定位精度 特征与参考环焊缝之间的距离误差小于士0.1m 参考环焊缝与参考点之间的距离误差小于±1% 可信度=90%时的环向定位精度 ±5° 6.2.6 超声裂纹检测的性能规格应满足： a)对于长度25mm以上，母材中深度 1mm以上或焊缝中深度2mm 以上的裂纹，POD大于90%。 b)裂纹尺寸量化精度满足表7的要求，特征定位精度满足表8的要求。 表7 裂纹尺寸量化精度 可信度 测量精度 深度 90% 能进行深度分级： < 12.5%WT 深度 90% (125%-25%)WT （25%～ 40%) WT > 40%WT 长度 90% ±10%WT（特征长度>100mm 10rom(特征长度<100mm) 宽度 90% 对于裂纹簇±50mm 表8 超声裂纹检测特征定位精度 可信度=90%时的环向定位精度 特征与参考环焊缝之间的距离误差小于 ±0.1m 参考环焊缝与参考点之间的距离误差小于±1% 可信度=90%时的轴向定位精度 ±5" 6.2.7 惯性测绘检测的性能规格应满足： a)地面参考点之间的距离小于1km的定位偏差不大于±1m。 b）单次检测应识别出曲率半径小于40DD（D为管道直径）的弯曲变形特征，重复检测应识别出曲率半径小于2500D的弯曲变形变化特征。 6.3 管道检测条件评估 6.3.1 管道运营方和检测服务方宜共同搜集待检测管道的相关信息，评估管道检测的适宜性，并对影响管道检测的限制进行更新和改造。 6.3.2 管道运营方应向检测服务方提供管道调查表(调查表示例参见附录E)，列出待怜管道的物理特征和运行条件，以便检测服务方评估管道条件是否满足检测器运行，评估应至少包括以下内容； a）收发球条件，包括但不限于： 1)收发球筒的尺寸：检测服务方应评估发球筒与收球筒尺寸的适用性。 2)操作空间：内检测器收发球操作时，应具有足够的操作空间。 b)三通，包括但不限于： 1）是否存在无挡条或挡板三通。 2)两相邻三通中心间距。 c)弯头，包括但不限于： 1)管道上存在的最小弯头曲率半径。 2)两相邻弯头之间的直管段长度。 3)斜接弯头及弯头斜接角度， 4)连续弯头。 d)阀门，包括但不限于， 1）阀门类型及阀腔内径。 2)如果存在单向阀，应确保其在清管器或检测器运行时能锁定在全开位置。 e）管道材质，包括但不限于： 1）钢材等级，制管类型。 2)管道壁厚分布和范围。 f) 运行条件，包括但不限于； 1)介质类型：介质类型影响检测技术的选择。 2)介质成分：腐蚀性介质可能损坏检测器。 3)介质流达；介质流速影响检测器运行速度，检测所需总时间和检测精度。当介质流速不满足条件时，可考虑调整输量或启用检测器调速功能。 4)介质温度：介质温度不应超出运行期间检测器所能承受的温度范围。 5)运行压力：大多数检测器都有适用的压力范围，运行压力过低或检测器前后压差过低会导致检测器驱动力不足，运行压力过高超过耐压设计会导致内检测器失效。 g)其他限制，包括但不限于： 1)管道内涂层。 2)管清洁度。 3)管道内径变化。 4）植入管道的探头。 5)管道大落差与跨越管桥。 6)管道机械支撑与非设计跨越。 7)管道内水合物与自燃物质。 6.3.3 管道运营方应提供与检测相关的管道建设，维修信息及历史检测结果。 6.3.4 检测服务方应根据管道调查表信息初步评估管道的可检测性。 6.3.5 检测服务方应在管道运营方的配合下对管道调查表中的内容进行现场勘测并进行最终评估。 6.3.6 管道运营方应对不满足检测器运行条件的管道及管道附属设施进行改造或更换。 6.4 检测器性能规格验证 检测器选定后，应进行检测器性能规格的验证，验证具体要求见第1章。 7 检测方案 根据实际情况编制检测方案并经管道运行方审批，方案应至少包括以下内容； a）管道基本情况。 b）运行条件评估及运行工艺要求。 c）现场勘测结果及风险分析，含硫管道接收检测器时应制订特别防护措施。 d)检测组织机构及检测程序。 e)检测跟踪、设标及地而测量要求《若采用便携式地而跟踪仪对检测器进行跟踪，应提前对全线设标点进行现场勘测，设标点间隔不宜超过1km，在大型河流穿跨越等特殊地段可加密设置)。 f)检测计划表。 g)清管方案， h)检测器运行方案。 i)数据下载要求。 j)捡测结果可接受性准则。 k）开挖验证要求。 l) HSE作业要求。 m）应急预案。 8 检测实施 8.1 作业计划 管道运营方与检测服务方宜共同确定内检测作业计划，重点考虑以下因素： a)检测实施时间。 b）运行工艺条件。 c）人力与物力资源。 d)进场条件。 e）健康，安全、环境因素。 8.2 设标与跟踩 8.2.1 参考点的选择 8.2.1.1 应使清地面探管仪，对清管和检测作业中所需要的卷考点进行踏线选点。 8.2.1.2 参考点宜设在管道里程桩等永久标识附近且容易进入的位置，以一定的间隔设置，通常不大于1km。 8.2.1.3 在大落差或阀室，穿跨越、大转弯等特殊位置宜加密设置参考点。 8.2.2 参考点位置测量 8.2.2.1 应测量、记录，维护参考点位置，作为管道永久资料的一部分。 8.2.2.2 宜采用永久磁铁安装在参考点贴近管道的正上方，作为永久标记。 8.2.3 跟踪监听 8.2.3.1 跟踪开始前应列好参考点位置清单，并根据参考点位置，数量提前制订跟踪计划。 8.2.3.2 检测服务方应根据现场需要提供相应数量的标识器，并确保每个标识器功能正常。 8.2.33 检测服务方应提前对跟踪人员培训标识器的使用方法，且保证所有跟踪人员都能正确操作。 8.2.3.4 清管及检测前，跟踪人员应提前对全线设标点进行踏线，设定跟踪进入路线，必要时可组织模拟跟踪。 8.2.3.5 检测器发出后，跟踪人员手持标识器根据事先设置的参考点进行跟踪，当检测管进较长时，可采取交替方式进行跟踪，在人员和车辆难以进入的区域，可在参考点提前埋设跟踪标识器。 8.2.3.6 检测器通过阀室，穿跨越等重要参考点时，跟踪人员应及时汇报运行状况。 8.2.3.7 如遇特殊情况，跟踪人员应立即向调度汇报。跟踪时如发现连续3个以上标识器没有触发，且通过震动等观察不到清管器/检测器通过，应启动相应的应急预案，及时寻找检测器或清管器具体位置。 8.3 清管 8.3.1 内检测前应进行清管，内检测清管一般分两个阶段，第一阶段为测径清管，第二阶段为强化清管。 8.3.2 清管作业流程按附录F执行并符合SY/T 5536或SY/T 5922要求。 8.3.3 选择清管器时，应考虑不同类型清管器的材质、清管能力和过盈量。 8.3.4 机械消管器应装有跟踪仪器，应根据生产要求，设定清管器跟踪方案并组织跟踪监听。 8.3.5 测径清管阶段可使用通过能力不低于日常维护所使用的清管器进行清管，并通过安装测径板等方式判断管道通过能力。测径板宜为铝制圆板，直径不应小于检测器的最小通过直径。若测径板发生损伤，应及时分析损伤原因，若通过分析确定损伤是由于管道存在较大变形，检测服务方应评估管道变形是否满足检测器通过条件。若评估后检测器无法通过且无法定位变形点的准确位置，应进行几何变形检测。 8.3.6 强化清管阶段使用直板、钢刷，磁力等清管器清管直至满足内检测的要求，并满足： a）在不含内涂层管道投运检测器前、钢刷、磁力清管器宜至少各运行一次，在含有内涂层管道，应根据情况选择合适的清管器。 b）清出杂质重量小于5kg或连续两次清管清出杂质重量相当且满足检测要求。 8.3.7 当有可能清出FeS 或其他自燃物时，应在开盲板前对收球筒采取注水，喷淋等防护措施。 |
联系我们
|
||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
微信联系客服
|
| 关于我们 | 联系我们 | 收费付款 |
| 服务热线：400-001-5431 | 电话：010-8572 5110 | 传真：010-8581 9515 | Email: bz@bzfyw.com | |
版权所有： 北京悦尔信息技术有限公司 2008-2020 京ICP备17065875号-1
51La
|
| 本页关键词： |
| SY/T 6597-2018, SY 6597-2018, SYT 6597-2018, SY/T6597-2018, SY/T 6597, SY/T6597, SY6597-2018, SY 6597, SY6597, SYT6597-2018, SYT 6597, SYT6597 |