bluuebunny/crossref_metadata_2025_split huggingface dataset:
Material Assessment of Canadian SAW Line-Pipes
Authors: Mak D. K. , Tyson W. R. 
Published: October 2016

Eight pipes, manufactured between 1952 and 1981, have been collected from various Canadian pipeline companies and tested. They include six pipes from the field made in the 1950’s and 1960’s of X52 grade, one experimental pipe manufactured in the early 1970’s of X65 grade, and a modern clean steel of X70 grade manufactured in 1981. The steels have been characterized by chemical composition, grain size, yield and tensile strengths, notch toughness (Charpy V-notch absorbed energy), and fracture toughness (J-integral and crack-tip opening displacement). The modern steel has much lower carbon content and much smaller grain size compared to the pipes manufactured in the 1950’s and 1960’s. The former is a fully-killed controlled-rolled steel while the latter are semi-killed ferrite-pearlite steels.
All eight pipes have ferrite-pearlite microstructures, with the average grain size ranging from 4 to 14 μm. The transverse yield strength was found to be significantly higher (by about 20%) than the longitudinal yield strength. Notch toughness and fracture toughness were similar for pipes manufactured in the 1950’s and 1960’s. In comparison, the modern steel has much higher toughness and higher strength.
J-integral and CTOD δ were found to be related by J = m σyδ with m = 1.8 and σy the transverse yield strength. The J-integral at 0.2 mm crack growth was consistent with a linear correlation with the upper-shelf Charpy energy. All the steels in this study fractured by ductile tearing in slow loading in spite of the low toughness of the older steels. It is suggested that, in the absence of Charpy upper shelf data, a reasonable representative toughness for resistance to axial surface flaws propagating by ductile tearing is J = 120±15 kJ/m2.
Seismic Hazard Assessment and Remediation of Pipelines
Authors: Fitzell Trevor P. , Wijewickreme Dharma K. 
Published: October 2016

The performance of pipeline systems under seismic loading is an important consideration in regions subject to earthquakes. This paper briefly describes a study to evaluate the vulnerability of a natural gas transmission system to seismic hazards, along with some of the remedial treatment options which are being considered. The study was carried out for BC Gas Utility Ltd. in the Greater Vancouver Region of British Columbia. The results of the study are being used by BC Gas in emergency response planning and remedial treatment activities to limit their risk exposure.
The paper describes the approach used to assess liquefaction and lateral spreading risks, and remedial treatment options which were considered. This involved generation of design seismic ground motions, seismic hazard mapping, geotechnical investigations to determine the subsurface conditions, and geotechnical and structural numerical modeling and analysis to assess pipeline performance and remedial treatment options.
Several different approaches to remediation are described; one involves ground treatment to reduce the risk of unacceptable ground deformations; another involves structural modifications to improve the resistance of the pipeline to seismic motions, while another makes use of directional drilling to re-align the pipe below infirm areas.
Analysis of Stresses on Buried Natural Gas Pipeline Subjected to Ground Subsidence
Authors: Kim Hyoung-Sik , Kim Woo-Sik , Bang In-Wan , Oh Kyu Hwan 
Published: October 2016

This study was initiated to examine the stress and deformation characteristics of the pipelines which were subjected to various environmental conditions in order to confirm their integrity. As the part of them, this paper presents the analysis results for the effect of ground subsidence combined with main loads on buried natural gas pipelines. The ground subsidence which can occur for buried gas pipeline has been classified to the three cases.
Finite element method was used to analyze the effect of ground subsidence on pipeline of 26 inch (0.660 m) and 30 inch (0.762 m) diameter used as high pressure (70 Kgf/cm2(686.4 Pascal)) main pipelines.
This paper shows the result of stress analysis for the pipelines subjected to those three case ground subsidence. Comparing these results with safety criterion of KOGAS (0.9 σ y), maximum allowable settlement and loads have been calculated.
In-Situ Evaluation of Pipeline Bedding and Padding Spring Constants
Authors: Tart Rupert G. , Hughes John M. O. 
Published: October 2016

Structural response analyses of pipelines using computer models, such as AutoPIPE, incorporate soil “springs” to model the restraint provided by pipeline bedding and padding. These “springs” are referred to as spring constants and are most frequently determined from a limited number of sources in the literature. In some cases representative soil properties are used with theoretical and empirical formulae such as those presented by Nyman (1984). This technique which is referred to herein as the ASCE technique has been used by Alyeska Pipeline Service Company (Alyeska) engineers in their calculations of structural response of the buried pipeline along the Trans Alaska Pipeline System (TAPS) (Hart et al, 1998).
This paper describes a field study at a pipeline inspection dig in which spring constants were determined directly from a series of field tests to develop a better understanding of the pipeline restraint the bedding and padding is providing for the pipe. Four other papers which cover other aspects of the work performed at this site are also a part of this conference (Hart et al, 1998, Norton et al, 1998, Stevick et al, 1998, Tonkins et al, 1998).
The field work included the drilling of multiple boreholes in which drive samples were taken at about 1 to 2 meter (3 to 5 foot) intervals. In each borehole, pressuremeter tests were also conducted at the same intervals as the drive samples. At two levels in the open pipe trench plate, load tests were conducted. Both nuclear and sand cone density tests were made at several levels in the pipe trench.
Results of these tests were correlated to each other. Stress strain relationships were developed from the pressuremeter test and plate load test data which were used independently to develop spring constants. Spring constants were found to vary with the strain level in the soils and were correlated to the drive sample blow count data. Recommended methods for estimating spring constants are presented.
Incorporating Muskeg Soil Shear Strength Into Buoyancy Control Design
Authors: Simmonds Gordon R. , Thomas Lance N. 
Published: October 2016

For the past four years, NOVA Gas Transmission Ltd. (NGTL) has included the backfill shear strength in buoyancy control design for natural gas pipelines built and operated in muskeg soil laden terrain. Incorporation of muskeg soil shear strength has resulted in major cost reductions. In typical muskeg soil laden terrain, the weighting requirement for NPS 4 and smaller pipelines has been eliminated, while the need for weighting of larger pipelines has been significantly reduced.
Traditionally, muskeg soil shear strength has not been considered due to an absence of adequate theoretical and performance data. NGTL has constructed a series of laboratory and field studies in an attempt to quantify the contribution of “muskeg soil shear strength.” The results of this research program, when combined with a rudimentary field investigation, are part of NGTL’s current buoyancy control design methodology for pipelines traversing muskeg soil laden terrain.
This paper presents a practical methodology used by NGTL for buoyancy control. Design examples are provided to calculate two design components; the maximum tolerable muskeg depth and optimum weight spacing. The paper concludes with a discussion of construction and operational considerations which influence buoyancy control design.
Determination of Pipe Roughness and Heat Transfer Coefficient in Pipeline Networks Using Multidomain Solution Method
Authors: Jelen Jaroslaw , Golshan Hossein , Rizopoulos Sandy 
Published: October 2016

In the development of new pipeline projects, all too often assumptions that are made in the initial stages of the business development opportunity are, for the most part, overly conservative. This inaccuracy is carried out through to the operation of the pipeline system and most assumptions do not change with subsequent expansions in the future until a conscious effort is made to determine and monitor those significant parameters that impact the pipeline’s overall performance.
In highly complex systems such as NOVA Gas Transmission Ltd.’s (NGTL’s) pipeline network, with over 21400 Km of pipe segments of different sizes and ages, for an accurate determination of pressure drop while 12 BCF of gas, on average, is flowing through our network, we need a technique to precisely assess the values of friction factor and heat transfer coefficient. These values have a profound impact on the accuracy of the hydraulic simulations.
The calculated values of pressure, flow rate, and temperature may be distorted by imprecise values of some parameters, such as friction factor or heat transfer coefficient. Thus, a proper estimation of these parameters is of great importance to the successful numerical flow simulation. Both friction factor and heat transfer coefficient are very difficult to measure; therefore, their values can only be assessed by solving an inverse problem (i.e. parameter identification process).
Since the parameter estimation procedure reported in this paper requires multiple solution of inviscid gasdynamics differential equations, describing the gas flow through the pipeline system, a multidomain solution method has been applied to effectively solve the parameter identification problem.
Improved Leak Detection by Method Diversity
Authors: Pichler Ruprecht M. J. 
Published: October 2016

Leak detection systems for liquid pipelines are installed to minimize spillage in case of a leak. Therefore reliability, sensitivity and detection time under practical operating conditions are the most important parameters of a leak detection system. Noise factors to be considered among others are unknown fluid property data, friction factor, instrument errors, transient flow, slack-line operation and SCADA update time. The opening characteristics and the size of leaks differ considerably from case to case.
Each software-based leak detection method available today has its particular strength. As long as just one or two of these methods are applied to a pipeline a compromise has to be found for the key parameters of the leak detection system.
The paper proposed illustrates how a combination of several different software-based leak detection methods together with observer-type system identification and a knowledge-based evaluation can improve leak detection. Special focus is given to leak detection and automated leak locating under transient flow conditions. Practical results are shown for a crude oil pipeline and a product pipeline.
Application of CFD to the Design of Multirun Meter Station With Ultrasonic Meters
Authors: Jelen Jaroslaw , Studzinski Wojciech , Brown Michael 
Published: October 2016

Designers of ultrasonic meter stations with headers do not have any experimental data which can help to determine proper location of the multipath ultrasonic meter within the meter run. The results of meter tests are limited to such configurations as a single 90° elbows and two elbows out of plane. Because of the variety of header layouts used in practice any experimental information related to this piping configuration will be of limited use in the design process.
The proposed approach is based on the application of Computational Fluid Dynamics (CFD) methods to the evaluation of header effects on ultrasonic flow meter using a commercial CFD code combined with a numerical model of the ultrasonic meter.
The numerical simulation of the flow field in the header and meter runs and subsequent integration of the obtained velocity field in a numerical model of multipath ultrasonic meter were used to determine the optimal meter position. This approach was validated against available experimental data on the ultrasonic meter performance downstream of single and double elbow. The comparison of simulations and test data has shown very good agreement of trends exhibited by the meter. The trends were replicated by the simulator within approximately 1% for X/D ≥5 and within 0.5% for X/D ≥9.
Pipeline Operations Training Using a Pipeline Simulator
Authors: Sutherland Dale , Lehmann Wolfgang 
Published: October 2016

This paper details the authors’ experiences in using a pipeline simulator in pipeline operations training programs.
Pipeline simulators allow trainees to practice basic and advanced operating techniques in a “safe” environment. In the early stages of applied operator training, the simulator usually represents a fairly simple, generic pipeline. This allows clear illustration of operational concepts with a focus on specific tasks. In more advanced stages of an operator’s training cycle, the simulator can provide an exact simulation of the pipeline that the trainee will have to control in the future. Realistic scenarios can be presented and operator trainees are able to exercise almost all tasks and deal with any possible incident that may occur during the operation of a pipeline. Accurate records detailing trainees’ operational decisions during a simulator exercise are maintained and help in determining the skill level of different trainees. This information allows pinpointing of specific areas where more training may be needed.
At the same time, pipeline operations training which uses a simulator can address certification requirements. A simulator allows a company to set standards, and then to test operational skills and knowledge against those standards in a quantifiable and controllable manner. Since the performance of a trainee during a simulator training session is fully recorded, companies can use this record as a measure when qualifying operators.
Development and Implementation of the NOVA Gas Transmission Ltd. Conservation and Reclamation Standard
Authors: Nixon Jeannette K. , Etherington Karen L. 
Published: October 2016

Currently, under Alberta’s Environmental Protection and Enhancement Act and regulations, all pipelines transporting natural gas with an index of 2690 or greater require an approval (Conservation and Reclamation Approval) for the conservation and reclamation activities associated with construction and reclamation of a pipeline. Administratively, Alberta Environmental Protection considers a pipeline requiring an Environmental Protection and Enhancement Act approval as a “Class 1” pipeline. The index is a calculation of length of pipe (in kilometers) multiplied by the outside pipe diameter (in millimeters).
NOVA Gas Transmission Ltd. (NGTL) has developed and implemented a Conservation & Reclamation (C&R) Standard to streamline the provincial C&R Application process. By re-formatting the currently accepted C&R Application into a Standard document, textual information submitted for an individual project has been reduced, without affecting the quality of environmental planning.
The Standard document compiles NGTL’s environmental standard practices and mitigative measures undertaken for all pipelines. It also explains NGTL’s decision-making processes during the design phase of a project.
The project-specific document presents issue focused site-specific environmental details in a simplified format The C&R Standard in combination with the project-specific submission form the NGTL C&R Application.
NGTL’s C&R Standard was developed within a concept which uses key building blocks to achieve industry accountability. This concept requires an organization to have performance measurement tools in place, and to demonstrate commitment to that performance in order to earn public confidence. Once this confidence is established and maintained, an organization can realize industry accountability. Considering this concept, NGTL leveraged past performance and experience by documenting our consistent approach to pipeline design, and our performance measurement criteria into the C&R Standard.
Fundamental to the development of the Standard was NGTL’s Platform Design Concept. Initially this design concept was adopted as an integral component of NGTL’s business need to reduce and streamline internal processes. This concept was then applied to external processes in an effort to meet business needs.
The Standard includes two primary components, Guiding Principles and Platforms. By combining NGTL Guiding Principles (‘What’ and ‘Why’) and NGTL Platforms (‘How’), the Concept provides a systematic design guide for all projects that allows NGTL to make the right decisions based on the right design criteria.
NGTL submitted the C&R Standard document to Alberta Environmental Protection for review in July 1997 and is currently implementing the Standard for all C&R Applications. This paper describes the development of the document as well as the implementation process and experience of the Standard.
Environmental Management for Regulated Industrial Wastes
Authors: Loven Larry 
Published: October 2016

This paper is to keep you informed of certain recent developments in the Alberta Energy and Utilities Board (AEUB) that is of particular interest to pipleline companies. Since these changes were first initiated, the Board has undertaken a significant transformation of the management of regulated wastes from the petroleum industry.
The passing of the G-58 guidelines will have far reaching effects on the business environment of the petroleum industry.
We have analyzed some of the more important aspects of this reform.
We continue to closely monitor changes from our western Canadian operations, particularly the impact of those changes on those generating regulated wastes in Alberta.
Response, Remediation and Risk Management of a Crude Oil Pipeline Spill
Authors: Doupe J. T. , Livingstone W. R. 
Published: October 2016

In December 1995, an oil spill was discovered along a section of pipeline located near the bank of a major river, less than 1 km upstream of the water supply intake of a southern Alberta community. The spill, which involved light crude oil, was observed at ground surface over an area of approximately 3 000 m2 at the top of the river slope and had also migrated downslope through the subgrade soils and along the groundwater table toward the river.
The initial emergency response activities consisted of removing and disposing of oil-stained vegetation and snow, and the containment and recovery of free oil pooled on ground surface. Subsequent subsurface assessments involved the drilling of test holes and boreholes, and installation of groundwater monitoring/recovery wells. Based on the results of these assessments, a remedial action plan was developed. As part of this plan, some of the impacted soils were excavated and placed in lined treatment cells for bioremediation. The limits of the excavation were based on field screening measurements and on soil clean-up criteria developed through an assessment of the human health risk and ecological impacts.
Investigations conducted at the site also indicated that phase-separated crude oil had migrated further downslope and had accumulated at the water table within the flood plain sediments adjacent to the river. Therefore, remediation systems were installed to recover the oil, recover and treat the impacted groundwater, and prevent further migration of the impacted groundwater and oil toward the river. Impacted groundwater recovered from the flood plain deposits was treated onsite and was then injected back into the flood plain deposits via an infiltration gallery. The performance of the pumping and remediation systems was monitored regularly and water samples were recovered from the treatment system, selected monitoring wells and the river. Based on the results of these analyses, the quality of local groundwater steadily improved and the zone of impacted water was effectively contained.
Analysis of Thermal Shock on Nuclear Power Station Pump
Authors: Qing Cao , Yimin Wu , Zhimin Zhang 
Published: October 2016

In this paper, a heat conduction equation and a dynamic thermoelastic equation are briefly deduced and established based on Continuum Mechanics.
First, an qualitative discussion is emphatically centered around the couple term and the dynamic term of the equation by means of the dimensional analysis and by considering the combination of the characteristics of the materials and of the thermal load effected on the nuclear power station pump under study.
Second, formulations of the FEM for non-coupled heated equations and quasi-static thermoelastic equations are derived in this paper.
Third, a half space thermal shock problem is used as a computational example in the highlighted research on the varying behavior of the dynamic thermal stress on the temperature slope. The conclusion of the paper provides reliable justification for applying the numerical method.
Finally, the distribution and variety of the temperature field, the thermal stress field and the thermal deformation field at various transient moments on the pump are given.
The Evolution of Risk Management at Enbridge Pipelines
Authors: Chorney Terris , Hamsher Denise 
Published: October 2016

1999 marks an important anniversary for Enbridge Pipelines Inc. of Canada and its U.S.-based affiliate, the Lakehead Pipe Line Company Ltd.: for 50 years we have been the primary link between the large oil production areas of western Canada and major market hubs in the U.S. midwest and eastern Canada. In retrospect, this strong history of success is chiefly due to thorough and logical planning and choice selection in all aspects of company endeavors.
At Enbridge, as in countless other firms in a wide-range of industries, decision making was often the product of expert consensus and years of solid experience in dealing with similar situations. This approach has worked well for Enbridge and our stakeholders for five decades, as evidenced by the reliability, efficiency, and safety record of our pipeline system. However, as the millenium nears, we are increasingly finding formalized processes that integrate quantitative models and qualitative analysis helpful in planning and execution for both the short- and long-term. Several broad trends at the root of this movement include the heightened pace of change; the increasingly complex web of relevant factors; the growing magnitude of the consequences associated with sub-optimal decisions; the need for thorough documentation; and the apparent benefits of a framework that enables objectivity and consistency. In short, an approach that completely and systematically evaluates the multitude of dynamic factors that affect the ultimate outcome of the matter at issue is necessary. Although the term “risk management” is now often used to describe this process, Enbridge — along with many other responsible firms in the pipeline operating and other industries — has always practiced the underlying principles.
This paper addresses the background of “risk management” in both the Canadian and U.S. pipeline industry, as well as accepted theory. It also encompasses the progression of risk management at Enbridge Pipelines, up to and including current initiatives. The usefulness of risk analysis, risk assessment, and risk management tools will be discussed, along with the overriding necessity of a well thought-out process, firm corporate commitment, and qualified expertise. Much of the focus will address the ongoing evolution and maturity of a comprehensive and well-integrated risk management program within the Enbridge North American business units. The criticality of maintaining focus on the core business function — in this case, pipeline operations — will also be addressed. In addition, past learning’s as well as future opportunities and challenges will be reviewed.