bluuebunny/crossref_metadata_2025 huggingface dataset:
Natural Hazard Database Application: A Tool for Pipeline Decision Makers
Authors: Leir Mark , Reed Michael
Published: March 2009

Trans Mountain Pipe Line Company Ltd. (TMPL) owns and operates an 1146 km NPS 24 low vapor pressure petroleum products pipeline between Edmonton, Alberta and Burnaby, British Columbia. In 1998 TMPL retained BGC Engineering Inc. (BGC) to start a three-phase geotechnical and hydrotechnical hazard assessment of the right of way (ROW) from Hinton, Alberta to Kamloops, British Columbia. As part of this work GroundControl was asked to develop an electronic database with which to capture the information generated by BGC during the hazard assessment work. This paper describes the development and evolution of the database application that accompanied the study to quantitatively assess and prioritize the geotechnical and hydrotechnical hazard potential along the pipeline. This paper describes how the database provides TMPL employees across British Columbia and Alberta access to the current results of the hazard assessment plus supporting information such as multi-temporal images and internal and 3rd party reports about the pipeline. The purpose of the database and the unique architecture and functionality that accommodates ongoing monitoring and inspections of slopes and stream crossings is provided. Database security, access, and information sharing unique to TMPL are also described. Benefits and costs of the application plus technical and business challenges overcome by TMPL, BGC, and GroundControl are discussed. Recommendations from TMPL and GroundControl for similar information management initiatives are provided and future work is described. This paper is targeted to pipeline managers who are looking for economical, practical, and innovative information management solutions for managing their natural hazards.
Pipeline Leak Detection Under Four Extreme Conditions
Authors: Hovey Diane J. , Farmer Edward J.
Published: March 2009

Many pipelines previously identified as unsuitable applications for leak detection — due to any one of a variety of “extreme” operating conditions — are now becoming subject to new regulations. As the trend toward more stringent regulation continues, more seemingly unsuitable lines will be effected. What constitutes an “extreme condition” to one may differ significantly from another, but a common thread connects them — the overwhelming sense of confronting the impossible. This paper examines leak detection performance under some of the most common extremes, those of temperature, operating conditions, products with difficult rheology, and situations in which a release poses immediate danger to life or the environment. The four case studies presented here demonstrate the effectiveness of combining static monitoring, “event detection” (monitoring for subtle changes in the energy and momentum of the product in the pipeline), and dynamic line-pack-compensated meter balance.
Effect of Interpass Temperature on Morphology, Microstructure and Microhardness of Welded API 5L X65 Steel
Authors: Trevisan R. E. , Santos N. F. , Fals H. C. , Santos A. A.
Published: March 2009

The overwhelming bulk of oil and gas in pipeline construction is done by welding the individual joints of pipe together. In a broad sense, welding is a metal-joining process wherein coalescence is produced by heating to a suitable temperature. In pipeline construction, this temperature has to be sufficient to render fusion of the joint. The mechanical and metallurgical properties and distortions usually present in weld structures are strongly influenced by preheating and interpass temperatures that are applied during the welding process. Basically, interpass temperatures depend on two factors: composition of the material and cooling rate. It is very important to choose the correct interpass temperatures, however, this is not a completely dominating matter. The objective of this paper is to present a study on the effect of different interpass temperatures on morphology, microstructure and consequently on microhardness of welded API 5L X65 steel. The welds were deposited by a Flux Cored Arc Welding Process and the heat input was held constant during all welding production. The interpass temperatures were calculated by different methods. Such temperatures were later verified experimentally. Temperature data were collected via a data acquisition system. The geometry and microstructure characterizations were performed via light optical microscopy and image analysis. These data were related to the different thermal cycles obtained. The results showed that the morphology, the microstructure and the microhardness of welded API 5L X65 steel were strongly influenced by the interpass temperature, revealing how important it is to choose the appropriate value.
Basis of the New Criteria in ASME B31.8 for Prioritization and Repair of Mechanical Damage
Authors: Rosenfeld M. J. , Pepper John W. , Leewis Keith
Published: March 2009

Mechanical damage in the form of dents has emerged as a key safety concern for pipelines. In response, ASME B31.8, with assistance from GTI, undertook a detailed review of industry research and operating experience with respect to various forms of mechanical damage. Revised criteria for prioritizing and effectively repairing damage in natural gas pipelines were developed based on the findings. The criteria address plain dents, third-party type damage, dents that affect weldments, dents affected by corrosion, and strain levels associated with deformation of the pipe section. This paper discusses the generalities of the scientific findings and basis for the changes to the Code.
Evaluation of End Fillet Details for Hot Tap Fittings
Authors: Rosenfeld M. J. , Baldwin Rick
Published: March 2009

Service failures in the welded connections of heavy-walled fittings attached to thin-walled line pipe were found to have been caused in part by inadequate attention to the critical need for dimensional balance in the attachment details associated with such components. The basis for present ASME Code specifications for end bevel and fillet weld dimensions of attached reinforcements was reviewed and evaluated. Nominal stresses in hot tap and stopple tee end fillet weld details were evaluated. Revisions to the ASME Code specifications for hot taps, stopples, and saddle-type branch reinforcements are proposed that are intended to prevent similar service failures.
Some Aspects on West-East Gas Transmission Pipeline Steels and Pipes
Authors: Feng Yaorong , Huo Chunyong , Ma Qiurong , Li Helin
Published: March 2009

The general situation of West-East Gas Transmission Pipeline Project has been introduced. The selection of operating pressure, material grade, steel pipe type, microstructure and the fracture control of the pipeline have been discussed according to international gas pipeline developing trends and related research achievements. The research and production of X70 grade acicular ferrite pipeline steels and spiral submerged arc welded pipes have been introduced finally.
Detection of Mechanical Damage Using the Magnetic Flux Leakage Technique
Authors: Clapham L. , Babbar Vijay , Rahim Thana , Atherton David
Published: March 2009

Since magnetism is strongly stress dependent, Magnetic Flux Leakage (MFL) inspection tools have the potential to locate and characterize mechanical damage in pipelines. However, MFL application to mechanical damage detection faces major hurdles, which make signal interpretation problematic: 1) the MFL signal will be a superposition of geometrical and stress effects, 2) the stress distribution around a mechanically damaged region is very complex, consisting of plastic deformation and residual (elastic) stresses, 3) the effect of stress on magnetic behaviour is not well understood. This paper summarizes a number of our studies concerned with mechanical damage and the effects of elastic and plastic deformation on MFL signals. The first series of experiments was conducted using uniaxial loading into the plastic deformation regime. Magnetic measurements made in situ with this uniaxial deformation showed that magnetic behaviour is far more sensitive to elastic, compared to plastic, deformation. Unloading the samples resulted in a combination of plastic deformation and residual stress. Subsequent ‘staged’ stress relieving heat treatments enabled us to progressively remove the residual stresses, and characterize their effects on magnetic behaviour and MFL signals. In a second series of experiments we simulated mechanical damage using a tool and die press to progressively ‘dent’ a number of plate samples. As with true mechanical damage, the resulting MFL signals arise from both geometrical and residual stress effects. Subsequent stress relieving heat treatments were used to separate and compare the ‘geometrical’ MFL signal from the ‘residual stress’ MFL signal.
Integrity Issues for Buried Piping Subjected to Overburden and Cyclic Traffic Loads
Authors: Tchorzewski R. M. , Jaske C. E.
Published: March 2009

Buried medium and small diameter piping at road crossings and under access roads within plant or oil terminal boundaries that is not protected by any sort of casing presents inspection difficulties because access normally calls for a selective or total excavation of such piping. Often, only when an oil or gas leak is suspected to originate in the area of a road crossing, is such piping excavated and inspected. Sometimes such a finding will stimulate inspections at other selected road crossings as well as failure analysis of the pipe where the oil or gas leak was found. One of the root causes of piping failure at road crossings and under access roads may be the overburden (the soil cover above the buried pipe) and cyclic traffic load stresses that are increased in the carrier pipe because of local areas of reduced wall thickness, mechanical damage such as a dent or surface cracking. In-service corrosion or damage of the uncased pipe at road crossings can lead to integrity problems since the original design assumptions or safety margin for such piping may no longer hold. This paper reviews a typical approach to analyze buried pipe design at road crossings and adds selected API RP 579 procedures to illustrate the analysis of fatigue loadings. A brief note on common inspection practices and techniques for buried medium and small diameter piping at road crossings and within plant limits is also included.
The Influence of Soil Chemistry on SCC of Underground Pipelines
Authors: Beavers J. A. , Worthingham R. G.
Published: March 2009

High-pH stress corrosion cracking (SCC) failures of underground pipelines have occurred in a wide variety of soils, covering a range in color, texture, and pH. No single characteristic has been found to be common to all of the soil samples. Similarly, the compositions of the water extracts from the soils have not shown any more consistency than the physical descriptions of the soils. On several occasions, small quantities of electrolytes have been obtained from beneath disbonded coatings near locations where high-pH stress corrosion cracks were detected. The principle components of the electrolytes were carbonate and bicarbonate ions and it is now recognized that a concentrated carbonate-bicarbonate environment is responsible for this form of cracking. Much of this early research focused on the anions present in the soils and electrolytes. This paper summarizes the results of analyses of soil and electrolyte data in which the relationship between the cations and the occurrence of high-pH and near-neutral pH SCC were evaluated.
Similkameen River Pipeline Crossing: The Repair Process
Authors: Phillips Dan , Fearon Peter
Published: March 2009

BC Gas Utility operates a natural gas transmission pipeline that serves the Okanagan Valley and Kootenay regions of British Columbia and a population of approximately 100,000. The pipeline runs from Kingsvale to Oliver and crosses the Similkameen River at Keremeos. During an over flight inspection (September 20, 1999), the pipeline was observed to be exposed in the river. Subsequent on-ground inspection revealed that the pipe had been exposed, was suspended up to 600 mm above the bottom of the river and had sustained damage to both the concrete and to the underlining PE coatings. Efforts to repair the pipeline insitu or replace it under emergency procedures were not successful and it was decided to implement a temporary repair prior to the upcoming spring runoff to protect the pipeline from further mechanical damage while the regulatory agencies approved a more permanent repair. Obtaining permission to install temporary protection proved to be very difficult and time consuming and it was approximately three months before the temporary protection could be constructed. Securing approval for the permanent repair was even more time consuming and problematic and it was another 6 months (September, 2000) before those approvals were secured. This paper presents the process that BC Gas went through to identify the problem, identify repair options and secure approvals for the repair.
Example of Quantitative Risk Analysis of a Gas Pipeline
Authors: Huo Chunyong , Zhuang Chuanjing , Lu Minxu , Li Helin , Li Guoxing
Published: March 2009

Quantitative risk analysis was carried out on a proposed natural gas pipeline based on preliminary data using the methods and models implemented in the PIRAMID™ software program. The high-risk areas were identified and the main causes of risk were analyzed. Measures to lower the calculated risk levels were developed, which will be taken into consideration in the design and construction of the pipeline.
Characterization of the Microstructure and Toughness of DSAW and ERW Seam Welds of Older Linepipe Steels
Authors: Gianetto J. A. , Mak D. K. , Bouchard R. , Xu S. , Tyson W. R.
Published: March 2009

The aim of the present work is to quantify the seam weld properties, including both weld metal and heat affected zone regions, for a series of double-submerged-arc welded pipe, and the base metal and bondline regions for an electrical resistance welded linepipe steel. The chemical composition, microstructure, microhardness, tensile properties, Charpy impact toughness and J-integral/crack-tip opening displacement fracture resistance were characterized for linepipe produced between 1953 and 1981. The toughness results of the base metal, heat affected zone and weld metal regions of the older (higher carbon) linepipes were significantly poorer than those obtained for a more modern low-C microalloyed linepipe steel. In the latter case the base metal, HAZ and weld metal regions failed by ductile fracture at room temperature in both fracture toughness (quasi-static) and Charpy impact tests. It was possible to show that there is a linear correlation between the J-integral at 0.2 mm crack growth and the upper shelf Charpy energy. It is, however, important to note that the Charpy transition temperatures of the older pipes are considerably higher than for the modern pipe. In the case of the electrical resistance weld, very poor toughness was observed for the bondline. Fracture occurred along the bondline in a brittle mode (cleavage) that was attributed to the formation of a coarse, relatively hard microstructure and the presence of inclusions along the bondline region. In addition, it was shown using base-metal BxB and Bx2B samples that initiation toughness is a function of the remaining uncracked ligament. This emphasizes the necessity of ensuring that the crack-tip constraint in the test specimens is similar to the constraint in the crack geometry being assessed.
Development of a FAD-Based Girth Weld ECA Procedure: Part II — Experimental Verification
Authors: Wang Yong-Yi , Rudland David , Horsley David
Published: March 2009

An ECA procedure specifically tailored to pipeline girth welds is developed under a PRCI (Pipeline Research Council International) funded project. This procedure of FAD (Failure Assessment Diagram) format incorporates some of the most recent developments in crack driving force, plastic collapse, and effects of weld strength mismatch match. The theoretical framework of this procedure is given in a companion paper. This paper focuses on the experimental verification of the procedure. Some particular issues related to girth weld ECA are discussed first. The experimental database includes both full-scale and wide plate test results. Most of the full-scale data are from pipes of API Grade X70 (483 MPa); a few were X65 (448 MPa) and X60 (414 MPa) grades. The diameter of the pipes ranged from 20 inch (508 mm) to 42 inch (1067 mm). The wide plate test data are taken from a PRCI project performed at the University of Gent. The plates were cut from an X60 36-inch OD 11.6-mm pipe. Surface-breaking defects were artificially introduced from the root side of the girth welds. The plates were loaded to failure in tension after the defects were fatigue pre-cracked. The girth welds had a range of yield stress levels ranging from 20% undermatching to 24% overmatching. In almost all the cases, the newly developed procedure proved conservative as compared to the experimental data. The comparison with the wide plate tests was particularly interesting with its wide range of weld strength mismatch levels. It was demonstrated that the inclusion of the weld strength mismatch in the new procedure improves the consistency and the accuracy of the predictions. It also showed that non-conservative predictions might result if the undermatching welds are not properly accounted for.
Effect of Strength Mismatch of Girth Weld on Safety of the West-East Pipeline
Authors: Zhuang Chuanjing
Published: March 2009

The West-East Pipeline is the first of high-pressure, high-grade steel (X70) and large diameter (Φ1016mm) gas transmission pipeline in China. Evidently, Safety of the Pipeline is the most important case that the gas company have to take care of. Previous study showed that strength mismatch of girth weld had great effect on the integrity of the pipeline. Overmatch is preferred for low-grade pipeline (steel grade is usually X60 or lower). As to the high-grade pipeline, in order to reduce the sensitivity of cold crack, hydrogen induced crack (HIC) and stress induced corrosion crack (SCC), etc., under-matched girth weld is recommended somewhere. In this paper, based on a lot of mechanical test results, the effect of different mismatched girth weld on property of the West-East Pipeline is analyzed. The study indicated that mismatch of girth weld has effect on property of the Pipeline, such as limit load, fracture toughness and threshold defect sizes, etc. According to the research results, some advices are presented for design, maintenance and repair of the Pipeline.
Recent Developments in the Design and Application of the PIPESAFE Risk Assessment Package for Gas Transmission Pipelines
Authors: Acton Michael R. , Baldwin Tim R. , Jager Eric E. R.
Published: March 2009

PIPESAFE is a hazard and risk assessment package for gas transmission pipelines, developed by Advantica for an international group of gas pipeline companies. Although the likelihood of failure of transmission pipelines is very low, the possibility of failure and a subsequent fire cannot be discounted. PIPESAFE provides the means to take consistent and informed decisions on risk issues, including infringements to pipeline design codes, uprating of pipelines (i.e. to operate at higher pressures), pipeline routeing and land use planning. The development of PIPESAFE was first reported at IPC ’98. This paper describes recent enhancements to the package, validation of the predictions against full-scale experiments and incidents, and modifications to the risk calculation methods. The paper also describes risk criteria developed in the UK and The Netherlands, the background to their development, and the use of PIPESAFE to generate risk criteria included in the latest edition of the UK pipeline code IGE/TD/1.
Pipeline Visualization, Simulation and Monitoring in Unstable Areas Affected by Soil Movements at Serra do Mar – Brazil
Authors: Musman Jacqueline V. R. , Costa Alvaro M. , Amaral Claudio , Santos Robson C. , Carnevale Maria Tereza , Rabaco Lis M. L.
Published: March 2009

In this work we discuss the importance of visualization, simulation and monitoring pipelines constructed in areas geologically unstable. In particular it is of great concern pipelines crossing Serra do Mar, in Brazil, where there are colluvium deposits subject to slow movements not traceable by a simple visual inspection most of the times. In order to guarantee the structural integrity of the pipeline it is necessary to measure the tensions transmitted by the ground to the pipeline. Knowing that the soil-pipeline interaction is extremely complex the implementation of an extensive program involving visualization, simulation and monitoring that includes not only the slope but also the pipeline becomes mandatory. This program seeks the collection of information that allows the establishment of a reliable interaction model. This model must be capable of providing operational control parameters and subsidize the decision of an intervention in the pipeline. Therefore the safety of pipeline operations can be maximized through instruction of operators and establishment of monitoring and inspection routines. Right now, in a joint effort of CENPES and TRANSPETRO, a complete set of visualization and numerical simulation software platform is available and it is being used to build a 3D model of all the geotechnical risky areas in Serra do Mar. Also the installation and operation of a pilot monitoring system, including piezometers and inclinometers on the slope and strain gauges on the pipeline, at three different pipelines crossing Serra do Mar, with data acquisition in real time is being undertaken.
A Dynamic Modeling of Pipeline Networks for Dense Compressible Fluids Tuned With Time Series of Plant Data
Authors: de Medeiros Jose´ L. , Costa Andre´ L. H. , Neto Joaquim P. P. , Arau´jo Ofelia Q. F.
Published: March 2009

We approached a phenomenological model for dynamic simulation of large pipeline networks carrying dense compressible fluids. In a typical application, the thermodynamic condition of the fluid is slightly supercritical, temperature is near environmental levels, pressure is high and the network size reaches hundreds of kilometers. Our model relies on decomposing the network on tube and vertex contexts. In the first context, continuity and momentum equations are written for each tube, jointly with a simplified flow relationship between density and pressure. These equations are treated via a finite element formalism. In the second context, network connectivity is taken into account through transient vertex mass balances. The set of tube-vertex time differential equations is integrated numerically. Model parameters are tuned with quasi-stationary time series of data via reconciliation procedures. Our case study is a 485km line for ethylene transportation between petrochemical plants. Results are useful for engineering, training, monitoring and inventorial applications.
Performance Evaluation of Above Ground Surveys for Locating External Corrosion in Pipelines
Authors: Ward Clive R. , McCallum Marcus , Masters Gary L. , Francis Andrew
Published: March 2009

Integrity management regulations require operators of high-pressure gas pipelines to consider various threats to pipeline integrity including time-dependent degradation due to corrosion. Depending on factors including age and operating pressure, a pipeline will require periodic integrity assessment. Methods available for assessing external corrosion are in-line inspection, pressure testing, or Direct Assessment, which is the subject of this paper. An analysis was conducted on data from a large diameter gas transmission pipeline built in the 1960’s. A 30Km section was investigated, using data spanning an 18-year period. The records analyzed included above ground surveys, high-resolution in-line inspection surveys, and site investigations. Assuming the in-line inspection represents true condition, it was found that the above ground surveys produced indications at between 80% and 90% of the in-line inspection features. Approximately 35% of the survey indications did not correspond to in-line inspection features. This information should benefit those wishing to implement Direct Assessment programs using Structural Reliability Analysis techniques.
Composite Reinforced Line Pipe (CRLP) for Onshore Gas Pipelines
Authors: Zimmerman Tom , Stephen Gary , Glover Alan
Published: March 2009

There has been a general trend in the natural gas pipeline transmission industry towards high-pressure pipelines using higher strength steels. However, as the strength has been increased, so have issues of weldability and fracture control. TransCanada PipeLines has been developing and testing a hybrid product since 1996 called Composite Reinforced Line Pipe (CRLP®) to address these issues. This is a patented technology developed by NCF Industries and licensed on a worldwide basis to TransCanada PipeLines. CRLP® is composed of high performance, composite material reinforcing a proven high-strength, low alloy steel pipe. The composite reinforces the steel pipe in the hoop direction, thereby increasing its pressure carrying capacity, while providing a tough, corrosion-resistant coating. This paper discusses recent research work concerning the use of CRLP® for large-diameter gas pipeline systems. Aspects discussed include analysis and design methodologies, full-scale testing, and field trials.
Detection, Localization and Quantification of Leaks in Pipeline Networks Using a Parameter Estimation Approach
Authors: Hemerly Costa Andre´ Luiz , Miranda de Souza Jaime Neiva , de Medeiros Jose´ Luiz
Published: March 2009

This paper presents a pipe network monitoring system based on a parameter estimation approach. The initial step involves the calibration of a dynamic pipe network simulator to the analyzed network, using a parameter estimation procedure. After the calibration, the network can be monitored, through an online simulation employing updated input data. If a properly statistical criterion indicates a discrepancy between the predicted and measured output variables, a possible leak is detected. Then, automatically, a routine of leak localization and quantification starts. This routine consists of an estimation procedure where the network model includes two additional parameters: the leak diameter and location in a pipeline section. This procedure is applied for each pipeline section selected by the user to be investigated. The section with the best match between predicted and measured data corresponds to the leak information that must be checked by the operation staff.
Probability of Exceedance (POE) Methodology for Developing Integrity Programs Based on Pipeline Operator-Specific Technical and Economic Factors
Authors: Mora Rafael G. , Parker Curtis , Vieth Patrick H. , Delanty Burke
Published: March 2009

With the availability of in-line inspection data, pipeline operators have additional information to develop the technical and economic justification for integrity verification programs (i.e. Fitness-for-Purpose) across an entire pipeline system. The Probability of Exceedance (POE) methodology described herein provides a defensible decision making process for addressing immediate corrosion threats identified through metal loss in-line inspection (ILI) and the use of sub-critical in-line inspection data to develop a long term integrity management program. In addition, this paper describes the process used to develop a Corrosion In-line Inspection POE-based Assessment for one of the systems operated by TransGas Limited (Saskatchewan, Canada). In 2001, TransGas Limited and CC Technologies undertook an integrity verification program of the Loomis to Herbert gas pipeline system to develop an appropriate scope and schedule maintenance activities along this pipeline system. This methodology customizes Probability of Exceedance (POE) results with a deterministic corrosion growth model to determine pipeline specific excavation/repair and re-inspection interval alternatives. Consequently, feature repairs can be scheduled based on severity, operational and financial conditions while maintaining safety as first priority. The merging of deterministic and probabilistic models identified the Loomis to Herbert pipeline system’s worst predicted metal loss depth and the lowest safety factor per each repair/reinspection interval alternative, which when combined with the cost/benefit analysis provided a simplified and safe decision-making process.
Investigation of Bolt Failures on a Gate Valve From a Natural Gas Pipeline
Authors: Owen D. M. , Beavers J. A.
Published: March 2009

This paper describes the results of an investigation of bolt failures that occurred in a gate valve from a natural gas pipeline. Failures of this type are not common; therefore, it was important for the operator to know the failure cause so that an effective mitigation strategy could be implemented. Accordingly, a standard failure analysis consisting of optical photography, metallography, and scanning electron microscopy examination of the fracture surfaces was performed. It was concluded that the failures were a result of environmentally assisted cracking (EAC). Coating the bolts was chosen as the simplest method for mitigation. Corrosion tests were carried out on stressed bolts with and without the coating to demonstrate its ability to mitigate the EAC.
Management System Audits: A Path Towards Safer Pipelines
Authors: Ator Lawrence , Ho Minh
Published: March 2009

The National Energy Board of Canada (NEB), a federal energy regulator, has implemented a management system audit program as a tool to verify compliance with its predominantly goal-oriented Onshore Pipeline Regulations, 1999 (OPR) [1]. The OPR allow individual companies to choose the most effective way to manage their pipeline systems. The audit program is based on expected elements that the NEB believes are necessary to meet the goals of the OPR. This paper will explain why these audits and expected elements are necessary and describe how goal-oriented regulations will enhance pipeline safety. The audits conducted to date have identified several challenges that the NEB and pipeline companies face in pursuit of the goal of safe pipelines; these will be described and possible solutions will be proposed. The overall objective of the paper is to explain the benefits of using a management system approach to direct a company’s pipeline integrity management program and what is required of companies to meet the expectations of the NEB.
Remote Operation of Unattended Pipeline Compressor Stations
Authors: Pinto Nunes Ildemar , de Vasconcellos Luiz Diogo , Frisoli Caetano
Published: March 2009

This paper describes pipeline compressor stations which are remotely monitored, operated and controlled from a central control station in Rio de Janeiro, Brazil. This is a result of TBG’s experience in design, construction and operation of compressor stations that are built for unattended operation. Only a small maintenance crew is necessary for routine tasks during normal working hours. In this connection, a complete set of resources has been implemented in order to ensure the required reliability level. This includes monitoring instruments (not only for the turbo compressors but also for all plant auxiliaries), redundant systems and protections, together with automatic control system for each of the relevant station components. Equipment status signals as well as alarm & trip signals are exchanged via a SCADA system with the Control and Supervision Center, CSC, in Rio de Janeiro. In addition, the CSC is capable of performing all relevant control actions such as start / stop compressor units and station auxiliaries, also remotely setting the station pressure and flow control points. The paper describes also the architecture and configuration of the supervisory and control functions which are performed by means of a SCADA system, along with the pipeline telecommunications system.
An Overview of Enbridge’s Pipeline Repair Program
Authors: McNeill David , Scott Bryan , McCoy Jackie , Thieson Dean
Published: March 2009

Enbridge Pipelines Inc. operates the world’s longest and most complex liquids pipeline network and terminals that link the producing areas of Western Canada to refineries and markets in Eastern Canada and the U.S. Midwest. As key components of Enbridge’s Integrity Management Program, In-Line Inspections and Repair Programs have been and will continue to be conducted on the more than 15,000 km of pipeline that make up the Enbridge network. Enbridge’s extensive use of internal inspection technology has resulted in the continued evolution and expansion of the Pipeline Repair Program. The Enbridge repair program is built on an established process. This process involves a team within the pipeline integrity group that assesses In-Line Inspection (ILI) information, validate ILI data, define a repair program, establish field repair teams, provide training & provide advice to repair teams, analyze field reports and maintain the program budget. The field repair teams are responsible for location of the repair sites, environmental and safety concerns, site excavation, defect assessment and repair & backfill. This process has to encompass the challenges of a pipeline network that traverses a variety of conditions, including varied soils, rock, water courses, population densities, regional environmental & land issues. These conditions have to be considered when choosing an ILI tool and when analyzing the data. Construction practices and equipment vary from region to region and repair teams have had to design and build equipment to meet these challenges. Field analysis personnel for all areas of the system are required to collect information on the land form, samples of soils, water, deposits on the pipe wall and a complete analysis of the anomaly and exposed seam & girthwelds. This paper will discuss the components of the program and will present the Pipeline Repair Program as a key driver that not only provides the assessment and repair of anomalies, but plays a key role in the development and testing of new technologies for field & office assessment tools.
Leak Detection Systems for Multiphase Flow: Moving Forward
Authors: Baptista Renan Martins , Wildhagen Moura Carlos Henrique
Published: March 2009

Multiphase flow is one of the most difficult situations for leak detection in pipelines, due to several reasons: the existence of two different and independent flow rates at each phase, five or more possible flow patterns, different fluid velocities at the phases, and sometimes a non-Newtonian associated behavior, due to the formation of an oil-water emulsion. There are two main groups for leak detection techniques: the models (or CPM, as stated in [API_1130]) which monitor the flow in real time (CVB, RTTM, PPA, etc.) from inside the pipeline (the instrument sensor is actually in physical contact with the fluid), and try to model the flow using a state estimator; and those based on dedicated external sensors (thermal, mass dispersion, etc) along the pipeline. Most of the technologies at the first group rely entirely on volumetric flow rate measurements, which turn them quite ineffective for multiphase flow. It is also relevant to consider that in some multiphase flow pipelines, the flow pattern changes quite random and intensively, allowing from a bubble pattern, to a slug pattern. There is sometimes the situation where a gas slug is big enough to fill entirely a short line and allow it to behave similarly to a gas pipeline, during a certain time (in fact, this was the case of one of the field tests this work will describe). This will bring unpredictability to those lines, in opposition to a regular single-phase line. Within this frame, the systems based on prediction approaches (hydraulic, statistical, etc, i. e., CPM’s), will show a good probability to be unreliable, inaccurate and not sensitive. The acoustic system is an exception to those two groups of technologies previously mentioned. It has, on one hand, a sensor that really touches the fluid (which would suggest it to be within the first group), but there’s no flow model behind it, on the other hand, but an acoustic sign analysis algorithm, acting somewhat like a piece of hardware. This paper will describe, discuss and report data for tests using an acoustic leak detection system at three different multiphase flow pipelines in Brazil, managed by PETROBRAS Production & Exploration Department.
Implementing a Safety and Environmental Management System Within Canadian Regulatory Agency
Authors: Postlewaite L.
Published: March 2009

The National Energy Board (NEB) believes that effective management systems are an integral part of managing safety and protection of the environment. Management systems allow for flexibility while ensuring that a comprehensive approach to managing risk is taken. This paper focuses on taking the systems approach to safety and environmental management in a quasi-judicial regulatory environment, particularly the NEB. The NEB is developing and implementing a Safety and Environmental Management System (SEMS) using the same “principle-based approach” as the internationally recognized ISO 14001 standard and OHSAS 18001 specification. It is the understanding of the NEB that it is the first regulatory agency in Canada to formally implement a safety and environmental management system to improve internal programs and processes. Under the goal-oriented Onshore Pipeline Regulations - 1999, the NEB requires pipeline companies to “develop and implement an environmental protection program to anticipate, prevent, mitigate and manage conditions that have a potential to adversely affect the environment”. While no regulations require the NEB to implement a management system, the NEB is proactively taking its own advice and meeting the same requirements of the companies it regulates. The development and implementation of the SEMS will help to consolidate and integrate internal NEB safety and environmental efforts as well as assist in clarifying their regulatory role, expectations, and responsibilities in regards to safety and environmental protection. The NEB has completed the first step of the development and implementation of the SEMS, including the development and communication of the NEB Environmental Policy and a draft of an integrated Safety & Environmental Policy; identification of objectives, targets and performance indicators; and improvements to existing programs and processes. The NEB Environmental Policy will be phased out once the integrated policy is approved and communicated. The second step includes conducting a detailed gap analysis to identify and prioritize areas for improvement as well as integrating the SEMS into the existing NEB business planning cycle. By fully incorporating the defined SEMS into the annual NEB business planning cycle, the management system approach will be used as the basis for setting internal safety and environmental priorities, work planning and continual improvement.
Reclamation of National Energy Board Regulated Pipeline Rights of Way: A Life Cycle Approach
Authors: Lien Kent
Published: March 2009

As part of its mandate, the National Energy Board (NEB) regulates the construction, operation, and abandonment of interprovincial and international pipelines. The primary legislation which directly and indirectly addresses reclamation of NEB lines are the National Energy Board Act and the associated Onshore Pipeline Regulations, 1999, and the Canadian Environmental Assessment Act. The NEB uses a life cycle approach to pursue appropriate reclamation of disturbed rights of way. Initially, reclamation related issues are addressed at the application stage. Subsequent to the application process, the actual implementation of reclamation measures occurs during construction of the line. Success of reclamation is monitored during the operational life of a line through inspection and auditing procedures, with additional measures being implemented as necessary.
Managing Pipe Facilities With GIS: A User Perspective
Authors: Gin Gordon , Thompson Stuart M. , Stortini David J.
Published: March 2009

The Facilities Data Manager (FDM), XFIALS and DaVinci Projects use a unique combination of geo-spatial data base technology, electronic document management and CAD technology to graphically maintain pipeline facilities data. The same common ORACLE 8i™ database (called ORION) hosts cathodic protection measurements, in-line inspection measurements and pipeline risk analysis data. AM/FM/GIS is used to support pipeline risk applications. We will follow the processes involved with using pipeline facilities data and pipeline measurement data to quantitatively calculate the risk of pipeline failures. Pipeline measurement data sets in our database include: mechanical damage susceptibility, pipeline inspections, close interval surveys, hydrostatic test and in-line inspection data.
Pipeline Integrity: The Use of Multiple Technology In-Line Inspection Tool
Authors: Slaughter Mark J. , Torres Carl R. , Massopust Peter R.
Published: March 2009

An aging pipeline infrastructure and more prescriptive regulatory policies are increasing pipeline operators’ demands for technological innovation and efficiency. Conversely, operators are struggling to find ways of minimizing the rate of increasing maintenance budgets. Developing an operating inspection technology that offers innovation and efficiency, cost-savings and, more importantly, a higher level of pipeline integrity is the universal challenge facing the pipeline inspection companies. The utilization of a multiple technology approach to in-line inspection (ILI) provides many solutions to this challenge. The ILI tool discussed in this paper, Linalog® COMBO, provides the operator with several multiple technology configurations [1] to choose from, depending on the specific pipeline inspection requirements. Some important benefits realized from these combined technologies are: accurately merged data from different inspection technologies; improvements in the identification and sizing of anomalies; more accurate integration of data; faster identification of high-risk anomalies. Our multiple technology approach to ILI now has a substantial history of providing inspections to the pipeline industry. This paper shall explain several case study examples of how this technology provides cost-savings, efficient regulatory compliance, and more informed, risk-based decisions.
Fatigue Analysis of Risers
Authors: Bolan˜os Rommel Burbano , Rivera Javier Espinosa , Campos Dante
Published: March 2009

This paper studies the fatigue problem of risers in marine platforms located in the Bay of Campeche, Mexico. Considering the future wave loads on these systems, the lifetime of these structures is obtained. Possibly, these systems have problems of fatigue in the zones where large stress concentrations appear. The risers fatigue analysis with a regular pipeline section is carried out taking into account operational and environmental load conditions. Due to operation, among others, the risers are subject to internal pressure, thermal expansion, and the type of fluid that transports. In order to take into account the environmental conditions one it is considered that the riser is subject to waves, current and ground movement, which were suitably modeled in the analysis. The supports on the platform, in the riser zone, were considered. They take into account the movements and their corresponding lateral stiffness. To evaluate the load cycles to which the risers are subject, for the study zone, the annual rates of occurrence and all the sea states have been considered. In addition, all the possible heights and directions of the wave that might be present in the Bay of Campeche have been considered the accumulated damage caused by the diverse cycles of stresses by means of the Palmgren Miner rule are assessed. This study includes the analysis of representative number of risers with different diameters and recent inspections. This allows us to know, in an approximated way, the present condition of the risers; it an give us suitable information for the calculation of the fatigue reliability and therefore define the present levels of structural safety of these facilities.
Mapping Bio-Physical and Cultural Values in the Mackenzie Valley: Preparing a Balanced Development Package
Authors: Blasutti Ange`le , Carpenter William , Booth Celeste , Ewins Peter J.
Published: March 2009

For the past decade, World Wildlife Fund Canada has been at the leading edge of GIS mapping initiatives and gap analyses regarding the establishment of protected areas across Canada’s lands and waters. In the Northwest Territories (NWT), we have led an open, multi-stakeholder exercise this past year to compile and digitise all existing bio-physical and cultural information for the Mackenzie Valley and NWT to produce high-quality readily available GIS maps showing the regional distribution of these values. These data will be available to all interested stakeholders to highlight information gaps and to consider the placement of pipeline related developments. Furthermore, consistent with the NWT Protected Areas Strategy (PAS) [1], communities and other groups can use the information to assist in identifying areas of high natural and cultural value which should be reserved for protection as pipeline development plans and approvals are being made. Based on these data, a defensible network of protected areas representing the diversity of landform features in the Mackenzie Valley natural regions can be established to provide all parties with greater certainty and confidence as the development proceeds. This poster shows some key preliminary results from this mapping project, describes the various data layers and analytical techniques used, and highlights spatial examples where pipeline routing, associated infrastructure and conservation/protected areas in affected natural regions could all be achieved and widely supported.
High Temperature Insulated Coating and Construction Methodology for the Mackay River Pipeline
Authors: Winter Cliff H. , Glowach Allan M.
Published: March 2009

Continued development of the oilsands in the Fort McMurray area of Alberta lead to a need for the MacKay River Pipeline. This heavy oil pipeline provides long-term, cost-effective transportation for production from the MacKay River area. The pipeline is designed to transport bitumen with little or no dilution (dry bitumen). In order to operate without diluent, the bitumen must be heated. Heat must be retained using a continuous layer of insulation, which ensures that viscosity remains low. The high operating temperature and the environment, through which the pipeline passes, were major challenges encountered during the design and construction phases. This paper focuses on the design, selection criteria, and testing of the coating system and discusses the important aspects of construction.
Geotechnical Aspects of Northern Pipeline Design and Construction
Authors: Oswell James M.
Published: March 2009

The design and construction of a northern pipeline differs in many respects from southern pipelines. The remoteness and environmental sensitivity of the region are only two commonly acknowledged issues. The geotechnical aspects of a pipeline in continuous permafrost or discontinuous permafrost are also different from pipeline designs in more temperate regions. There have been several successfully constructed and operated pipelines in northern Canada and Alaska. These facilities provide an important precedence for the design and construction of future northern pipelines. The geotechnical aspects covered in this paper will include the differences in oil and gas pipelines relative to geothermal impact on the ground, the importance of route selection and terrain analysis, protection of permafrost, slopes design, frost heave and thaw settlement impact and mitigation, and a discussion of some of the lessons learned from previous projects.