2010 国际管道会议(IPC2010)--(5--6)

专题五：GIS/数据库开发IPC2010-31147USING GEOSPATIAL SOLUTIONS TO MEET DISTRIBUTION INTEGRITYMANAGEMENT REQUIREMENTSRobert A. McElroy, PENew Century Software, Inc.Fort Collins, CO USAABSTRACTRecently enacted U.S. regulations will require distribution system operators to develop Distribution Integrity Management Programs (DIMP). The purpose of this regulation is to reduce system operating risks and the probability of failure by requiring operators to establish a documented, systematic approach to evaluating and managing risks associated with their pipeline systems. Distribution Integrity Management places new and significant requirements on distribution operators’ Geographic Information System (GIS). Operators already gather much of the data needed for meeting this regulation. The challenge lies in efficiently and accurately integrating and evaluating all system data so operators can identify and implement measures to address risks, monitor progress and report on results. Similar to the role geospatial solutions played in helping transmission pipeline operators meet Integrity Management Program requirements, this paper will discuss the role GIS can play in helping operators meet the DIMP regulations. Data requirements, storage and integration will also be presented. The paper will give examples of how risk-based decision making can improve operational efficiency and resource allocation.IPC2010-31339 LESSONS LEARNED FROM SUPPORTING A GEOHAZARDMANAGEMENT PROGRAMNeil Ripley, M.Sc., GISPSenior GISAnalyst/DeveloperBGC Engineering500-1045 Howe St Vancouver, BC, Canada,V6Z 2A9nripley@bgcengineering.caTrevor Simpson B.Sc.,A.Dipl.T.Geomatics ManagerBGC Engineering500-1045 Howe StVancouver, BC, Canada,V6Z 2A9tsimpson@bgcengineering.caMark Leir, P.Eng., P.Geo.Senior EngineeringGeologistBGC Engineering500-1045 Howe StVancouver, BC, Canada,V6Z 2A9mleir@bgcengineering.caABSTRACTThere are a number of geomatics tasks required to support a Geohazard Management Program (Program). For the program implemented by BGC Engineering Inc. for several midstream pipeline operators, these tasks range from identification of potential geohazards (landslide, river erosion), to setup and support for field navigation, through to geohazard database management. Doing these in an efficient and effective manner requires substantial amounts of spatial data and a toolset containing both software and hardware components.For this Program geohazards are classified as hydrotechnical (e.g. a pipeline crossing a river) or geotechnical (e.g. a pipeline traversing a slope). Lists of potential geohazards are generated and provided to field crews who then navigate to each site and perform a field inspection. Navigation and inspection observations are accomplished with the aid of a ruggedized laptop connected to wireless GPS. Upon return from the field, sites are uploaded to CambioTM, an internet database for managing geohazards. Each site is assigned a frequency of action commensurate with the estimated level of risk. Assigned actions include follow-up ground inspections, detailed investigations, monitoring, maintenance and mitigation. An audit trail of site inspections, surveys and mitigation reports, photos, and site survey drawings, are all available for review within CambioTM, allowing access to the information from any site with an internet connection. This paper will present an overview of the Geohazard Management Program from a geomatics perspective, highlighting the integration of geomatics tools into a system designed to be used by engineering personnel, field technicians, and project managers.IPC2010 – 31382INTEGRATING ILI DATA WITH PUBLICLY AVAILABLE MAPPINGSOLUTIONSGrant A. ColemanBJ Pipeline Inspection Services 4839 90th Ave SE Calgary, AB, Canada,T2C 2S8 Phone: 403.531.5300 gcoleman@bjservices.caScott J. MillerBJ Pipeline Inspection Services 4839 90th Ave SE Calgary, AB, Canada,T2C 2S8 Phone: 403.531.5300smiller@bjservices.caABSTRACTToday’s’ high resolution ILI tools often incorporate extremely accurate Inertial Mapping Units (IMU) which provide spatial coordinates for every feature within a pipeline. This data may be useful across many levels of an organisation and so it is important to make the information available and practical. Google provides two near universally available mapping packages that may be easily leveraged to display GIS style data while in the field or in the office; GoogleMaps™ displays 2D information, while Google Earth™ provides 3D viewing.This paper presents several case studies where the use of Google Earth imagery combined with high resolution; inertially mapped MFL data provides immediate value to the pipeline operator.IPC2010-31438 INTEGRATING PIPELINE DATA MANAGEMENT APPLICATION AND GOOGLE MAPS DATASET ON WEB BASED GIS APPLICATION USING OPEN SOURCE TECHNOLOGY SHARP MAP AND OPEN LAYERSArie WisiantoPT PERTAMINA GAS Bontang, IndonesiaHidayatus SaniaPT PERTAMINA GASBontang, IndonesiaOki GumilarPT PERTAMINA GASJakarta, IndonesiaABSTRACTDevelopment of web based GIS application often requires high cost on base map datasets and software licenses. Web based GIS Pipeline Data Management Application can be developed using the benefit of Google Maps datasets combined with available local spatial datasets resulting comprehensive spatial information. Sharp Map is an easy-to-use mapping library for use in web and desktop applications. It provides access and enables spatial querying to many types of GIS data.The engine is written in C# and based on the .Net 2.0 frameworks and provides advantages for integration with Pipeline Data Model such as PODS using .NET technology. Sharp Map enables development of WMS and web services for serving pipeline data management information oninternet/intranet web based application. Open Layers is use to integrate pipelines data model and Google Maps dataset on single map display with user friendly and dynamic user interfaces. The use of Sharp Map and Open Layers creating powerful Pipeline Data Management web based GIS application by combining specific information from pipelines data model and comprehensive Google Maps satellites datasets without publishing private information from local datasets. The combination on Sharp Map, Open Layers, Google Maps datasets, and .NET technology resulting a low cost and powerful Pipeline Data Management web based GIS solution.Impact zone of the event then we can calculate their consequences and finally we can figure their risk.Keyword: GIS, Sharp map, Open layers, PODS, google map DatasetsIPC2010-31635FROM CAD TO GIS TO THE GEOWEB - A NATURAL EVOLUTIONSteve AdamAdamlabs Inc.Calgary, Alberta, CanadaABSTRACTComputer hardware and software have played a significant role in supporting the design and maintenance of pipeline systems. CAD systems allowed designers and drafters to compile drawings and make edits at a pace unmatched by manual pen drawings. Although CAD continues to provide the environment for a lot of pipeline design, Geographic Information Systems (GIS) are also innovating pipeline design through routines such as automated alignment sheet generation.What we have seen over the past two or three decades is an evolution in how we manage the data and information required for decision making in pipeline design and system operation.CAD provided designers and engineers a rapid electronic method for capturing information in a drawing, editing it, and sharing it. As the amount of digital data available to users grows rapidly, CAD has been unable to adequately exploit data’s abundance and managing change in a CAD environment is cumbersome. GIS and spatial data management have proven to be the next evolution in situations where engineering, integrity, environmental, and other spatial data sets dominate the information required for design and operational decision making.It is conceivable that GIS too will crumble under the weight of its own data usage as centralized databases become larger and larger. The Geoweb is likely to emerge as the geospatial world’s evolution. The Geoweb implies the merging of spatial information with the abstract information that currently dominates the Internet. This paper and presentation will discuss this fascinating innovation, it’s force as a disruptive technology, and oil and gas applications.专题六：设施完整性管理IPC2010-31064FINITE-ELEMENT MODEL-BASED FAULT PROGNOSIS ONKEYCOMPONENTS OF THE RECIPROCATING COMPRESSORWenqing LuResearch Center of Oil &Gas Safety Engineering TechnologyLaibin ZhangResearch Center of Oil &Gas SafetyEngineering TechnologyWei LiangResearch Center of Oil &Gas Safety EngineeringTechnologyShuguo LiResearch Center of Oil & GasChina University of Petroleum, Changping, Beijing 102249, China ABSTRACTThe reciprocating compressor has become one of the most important equipments in petroleum and chemical industry. Study on vibration of the reciprocating compressor has a great significance to monitor the safety and reliability of the compressor. But it’s very difficult to predict the compressor and achieve the desired goal due to the complicated structure and operational aspect of the compressor. Experimental solution is expensive and time consuming. Therefore, finite element analysis (FEA) method is proposed to predict and locate the breakage of several key components on reciprocating compressor in compressor station.Non-destructive fault diagnosis and troubleshooting of the compressor can be achieved by application of FEA. The reasonable and simplified 3D model of the reciprocating compressor, which is validated with the actual prototype, is built by a CAD drawing software-SolidWorks. Then the ANSYS FE model is created by importing the 3D model into a FEA software-ANSYS. The ANSYS FE model can be used for stress analysis as well as intrinsic property analysis of the structural components. In this paper there are several ANSYS FE models of key components presented, including crankshaft, connectingrod, crosshead and air valve. Then FEA method is applied to the fault localization of those components. According to the simulation results, the sites vulnerable to failure can be fixed on key components. The conclusions are consistent with the problems during the normal operation. Therefore, FEA is an effective and prospective method on fault prognosis of the reciprocating compressor.IPC2010-31065 STORAGE TANK FLOOR AND WALL DEFECT IN-SITU INSPECTION WITH ULTRASONIC GUIDED WAVE TECHNIQUEZhanjun FengWeibin WangWenqiang Tong Petrochina Pipeline R&D Center, kjfengzj@ Langfang, Hebei, China, 065000Keyi YuanZandong HanYifang ChenKey Laboratory for Advanced Materials Processing Technology, Dept. of Mech.EngineeringTsinghua University, Beijing 100084, ChinaABSTRACTLarge storage tanks for oil storage are widely used in petrochemical industry.economic safety. Owing to their unique potential for long-range,solution in the development of an on-board structural health-monitoring (SHM) system, providing assessment of structural integrity for storage tank floor and wall defect in-situ inspection. This paper presents this application by focusing on their propagation through the plate structure. Even very small mechanical discontinuity or geometry change of plate structure, e.g. corrosion defect on tank floor, will influence the propagation characteristic of the guided waves. These effects are measured as mode changes, frequency shifts or filtering, reflection and diffraction of new ultrasonic modes or overall distortion of the original ultrasonic signals. By capturing and analyzing these changes we can deduct the corrosion defect of the tank floor and wall which causes the ultrasonic signal change and interactions. The T/R transducers are required to be attached on the outer edge of the tank floor and outer surface of the tank wall. The technique is developed based on the Lamb wave transmission tomography. Starting from the dispersion curve and choosing the appropriate wave mode, the propagation of the guided waves in the tank floor and wall has been carried out through numerical simulation and the experiment has been conducted for verification using the fullsize oil storage tank. The low frequency guided waves can propagate longer distance in planar and tubular structures. The later has been already used in pipeline inspection. The complexity of the application of ultrasonic guided wave in tank floor inspection lies in the object containing multiple lap joint welds along the large diameter of the tank (up to 100 m) and the complicated reconstruction of the two-dimensional defect distribution information.The main scope of the investigation was the application of the ultrasonic transmission tomography for localization of nonuniformities of inside tank floor, taking into account ultrasonic signal losses due to the loading with oil on the top and ground support at the bottom for the tank floor, and the loading with oil inside for the vertical tank wall.IPC2010-31080RESEARCH ON ACOUSTIC EMISSION IN-SERVICE INSPECTION FOR LARGE ABOVE-GROUND STORAGE TANK FLOORSMingchun Lin*PetroChina Pipeline R&DCenter Langfang, Hebei, ChinaMingchun Lin*PetroChina Pipeline R&DCenterLangfang, Hebei, ChinaWeibin WangPetroChina Pipeline R&DCenterLangfang, Hebei, ChinaLei ZhangShenyang Dispatching Center of PetrochinaPipeline CompanyShyang, Liaoning, ChinaYi Sun PetroChina Pipeline R&D CenterLangfang, Hebei, ChinaABSTRACTMuch manpower is needed and a lot of materials are wasted when the floor of large above-ground storage tank (AST) is inspected with conventional methods which need to shut down the tank, then to empty and clean it before inspection. Due to the disadvantages of that, an in-service inspection method using acoustic emission (AE) technology is presented. By this mean the rational inspection plan and integrity evaluation of tank floors can be constructed. First, specific inspection steps are established based on the acoustic emission principle for large AST’s floors and the practical condition of AST in order to acquire the AE corrosion data. Second, analysis method of acoustic emission dataset is studied. Finally, maintenance proposes are provided based on results of analysis for the corrosion status of the tank floors. In order to evaluate the performance of our method, an in-service field inspection is practiced on product oil tank with a volume of 5000 cubic meters. Then a traditional inspection procedure using magnetic flux leakage (MFL) technology is followed up. Comparative analysis of the results of the two inspection methods shows that there is consistency in localizing the position of corrosion between them. The feasibility of inservice inspection of AST’s floors with AE is demonstrated.IPC2010-31104THE REMAINING LIFE PREDICTION AND INTERNAL INSPECTION INTERVAL ANALYSIS FOR LARGE-SCALE CRUDE OIL STORAGE TANKJian ShuaiFaculty of Mechanical and ElectronicEngineering,China University of Petroleum-BeijingBeijing, ChinaKejiang HanFaculty of Petroleum Engineering China University of Petroleum-BeijingBeijing, ChinaABSTRACTAs an important production facility, storage tank plays a more and more important role in the storage and transportation of crude oil and chemical product. The remaining life prediction of storage tank is to forecast the thinning trend of plate thickness, and forecast remaining life on the premise that remaining strength of storage tank meets the tank operation and safety requirements. Maximum corrosion depths of tank bottom plate obey the maximum extreme value distribution. Based on maximum extreme value distribution and statistics of corrosion data, the calculation formula of theformula derivation. Compared with API STD 653 and EEMUA 159, inspection interval specified by China standard SY/T 5921 isconservative. The remaining life of a certain crude oil storage tank (tank A) in china is determined by the remaining life of tank bottom plate. The remaining life of tank A at the reliability of 0.99, 0.999 and 0.9999 are 25 years, 20 years and 17 years, respectively. For the acceptable failure probability of 1×10-4, the inspection interval of tank A can be extended from required 5-7 years specified by China standard SY/T 5921 to 17 years. The remaining life of crude oil storage tank predicted by the method proposed in this paper can be used as an important reference in the determination of inspection interval and tank’s maintenance.IPC2010-31352 RELIABILITY BASED FACILITY RISK ASSESSMENTWilliam V. Harper, PhD,PEOtterbein College Towers Hall 139, 1 GroveSt.Westerville, OH43081-2006Ph: (614)823-1417 Fax: (614)823-3201 WHarper@David J. StuckiOtterbein CollegeTowers Hall 133, 1 GroveSt.Westerville, OH43081-2006Ph: (614)823-1417 Fax:(614)823-3201DStucki@Taylor M ShieDNV Columbus, Inc.5777 Frantz RoadDublin, OH 43017-1386Ph: (614)761-1214 Fax:(614)761-1633Taylor.Shie@ Ray J. DaviesDNV Columbus, Inc.5777 Frantz RoadDublin, OH 43017-1386Ph: (614)761-1214 Fax: (614)761-1633Ray.Davies@ABSTRACTPipeline facilities are ageing and will likely soon come under closer scrutiny from federal regulation. It is imperative that sound reliability based inspection procedures be established that meet the goals of an organization while controlling time and cost. DNV Columbus has developed a statistically based sequential inspection decision support system for this purpose. This system was implemented for an international petroleum company and quickened the inspection process by making a “stop inspections” or a “continue inspections” decision after each inspection at a facility.This system allows inspections to be stopped because the desired reliabilitybeen met based on inspections that did not reveal a significant amount corrosion. At this point, further sampling would provide minimalvalueto the reliability assessment.Inspections can also be stopped because the estimated reliability metrics have not been met. Stopping for this reason indicates the facility may need more significant repair or replacement. Engineers and managers can then make a decision that includes a variety of factors including safety andthe economic feasibility of alternates.In contrast, when using this method, inspections continue because insufficient data have been collected to determine whether the reliability metrics have been met. This system will be illustrated with actual data. It will also describe the use of four key safety factors in developing site specific reliability goals. These factors are consequence, off site migration probability, product type, and facility size.This work can result in a major savings in time and financial expenditures for an inspection cycle. This reliability based inspection methodology leads to the following improvements: 1) Quicker decisions to save time and money, and allows more sites to be inspected in a timelier manner, 2) The reliability of a group of inspections performed is quantified after each inspection, 3) Results at a facility are broken down by database driven categories into a scorecard, 4) Methodology kept generic to be easily adapted to a wide variety of situations.IPC2010-31357IN-LINE INSPECTION TECHNIQUES FOR “NON-PIGGABLE” LIQUIDPIPELINESDamir Grmek, P.EngSr. Engineer, Facilities IntegrityEnbridge Pipelines Inc.Edmonton, Alberta, CanadaABSTRACTWhile in-line inspection tools have been around for many years, the primary focus for this technology has always been on long sections of mainline pipe. The recent increased attention on facility integrity, as well as US Department of Transportation (DOT) baseline assessment requirements, have made it necessary to develop inspection tools and techniques for pipelines that have previously been considered non-piggable.Within industry, the term non-piggable has been used to describe pipelines that cannot be inspected with traditional free swimming mainline inspection tools using standard launch and receive traps. Typical reasons for classifying a pipeline as non-piggable include:No launch or receive facilities,Mechanical design (number/type of bends, diameter changes, offtakes etc.) Operating conditions (zero/low/high pressure, zero/low/high flow, type ofproduct, pipeline cleanliness etc.) Within the Enbridge system, a lack of launch and receive facilities has been the main obstacle on laterals anddelivery/receipt pipelines. However, mechanical design and operating conditions have been factors on certain pipelines.The preferred method to inspect these pipelines, whenever possible, is to use in-line inspection tools, as opposed to other options such as External Corrosion Direct Assessment (ECDA) or hydrostatic test.While inspecting these short sections of pipe has proven challenging, various in-line inspection tools and techniques have been developed to meet this requirement. This paper will discuss some of the challenges faced and different solutions that have been developed to successfully inspect these types of pipelines.IPC2010-31368SAFETY CULTUREMARCELO GARCEZ LOPESPETROBRAS Transportes S.A. - TRANSPETROGuarulhos, São Paulo, Brasilmarcelogarcez@.brABSTRACTThe occurrence of accidents which resulted in lost work time, since 2007, prompted the Company to invest in a new Educational Program to prevent accidents. The program was divided into several parts. One of these parts was the project on Safety Culture. The Safety Culture project had been implemented since September, 2009, at PETROBRAS TRANSPORTES S.A. –TRANSPETRO, in Guarulhos, São Paulo, Brazil. The project had intended to change the employee’s behavior, informing the employees, who are exposed the risks, to know and understand the risks associated with their tasks, delivering a higher perception of the risks and making possible a change of behavior resulting in employees reaching a safe attitude.The Safety Culture project was developed specifically for TRANSPETRO. The project was divided in three parts: Safety Culture Visual, Procedures and Leading with Safety. This paper will discuss the content one part, Safety Culture Visual.The Safety Culture Visual concept has as its main objective to completely change the visual of the Company. In this concept about Safety Culture Visual, the Company wanted to demonstrate its concern with employee’s safety. Although the goal of the project was to change worker’s behavior, it wasobjective of the Company’s culture.By changing your visual, the company can demonstrate to workers that they are interested in their safety and their lives. Posting warning signs at the entrance of the company, at the entrance of the offices, streets, work areas, and other settings where employees must go were all small signs that the company had started to focus on the importance of having a safety culture. By installing warning signs everywhere, workers who are exposed to the risks can better know and understand the risks associated with their tasks. This greater awareness of the risks associated with their tasks provide the employee a greater insight to the risks, enabling a behavior change and helping them reach a complete attitude on safety.The methodology that the Company has been using to implement this change in vision is an “Andragógico Model”, exploring the experience of the person; with a focus on the day by day work and daily life situations. The project has been applied in the form of weekly leadership meetings, where everybody has the opportunity to suggest ideas as to promote the change.Expecting results and consequence of the Project:• to turn the concept of safety into a real value to the worker;• to preserve the integrity and to give value to the life of the employee;• pursue a lasting and stable changing of behavior, with a culture based on safety; and• to support the management safety system and reduction of accidents.This project has reduced worker's exposure to risks and has diminished the number of industrial accidents. Accidents with lost time: using a different concept to deal with safety, focusing directly on the behavior of the worker, leading the worker to a shaper perception of the risks and thus enabling a change of behavior towards a safer attitude.IPC2010-31460 DETERMINING THE YIELD STRENGTH OF IN-SERVICE PIPE USINGHARDNESS TESTINGShadie Radmard, P.Eng. & Monique Berg, P.Eng., MBAEnbridge Pipelines Inc.Facilities Integrity10201 Jasper AvenueEdmonton, Alberta, Canada, T5J 3N7Shadie.Radmard@ Monique.Berg@ABSTRACTEnbridge Energy Partners (EEP) (“Enbridge”) purchased a Tank Storage Facility in Cushing, Oklahoma in 2004. After the acquisition, it was discoveredfor some of the pipe segments in the tank facility.was determined that piping at the Cushing Facility should be operating under “low stress”1 conditions. To determine if this condition could be met, the internal design pressure and yield strength (“YS”) were required for each pipe segment. Without pipe records, neither the internal design pressure, nor the YS was known.In 2007, a project was undertaken by Enbridge to inspect and test all pipe segments identified to have missing pipe records. The project’s objectives were:(1) To establish procedure and process for nondestructive evaluation of tensile properties of in-service pipe(2) To collect pipe characteristic information (i.e. diameter, wall thickness)(3) To determine if the piping could be considered low stress piping; and(4) If the piping could not be considered low stress, to select a course of action from the following options:a. Lower the Maximum Operating Pressure (MOP)b. Hydrotest the pipingc. Remove/Abandon all unnecessary lines.Two existing reports justified the use of hardness as a means of determining the YS of in-situ piping. Based on these reports, Enbridge developed the following project scope:(1) For all piping with missing records:a. to collect hardness data of in-situ pipe using two portable hardness testers (any hardness measurements taken with these portable hardness testers are hereinafter referred to as “field hardness”)b. to measure wall thickness of in-situ pipe (2) To collect field hardness, lab hardness, YS and tensile strength data of pipe coupons of various diameters in order to establish a field hardness to YS correlation(3) To determine the YS of the in-situ pipe using field hardness measurements and the established field hardness to YS correlation determined above(4) To determine if the pipe could be considered low stress at existing operating pressures(5) For pipe segments not deemed low stress at existing operating pressures, to calculate an internal design pressure (Allowable Working Pressure or “AWP”2) required to maintain low stress conditions.This paper will describe the method used to determine YS and AWP of in-service piping using field hardness and compare the results obtained using this method to the YS and AWP determined using CFR Title 49 Part 195.106.IPC2010-31492 THE REMAINING STRENGTH OF CORRODED CASING WITH COMBINEDHOOP AND LONGITUDINAL STRESSRobert B Francini Kiefner & Associates, Inc. Worthington, OH, USA。