bluuebunny/crossref_metadata_2025_split huggingface dataset:
Practical Diagnostics of Russian Gas Transmission Pipelines
Authors: Kharionovsky V. 
Published: October 2016

Unified gas transmission system which includes about 140 thousand kilometres of pipelines has been developed in Russia. The mains of pipelines cross the regions with difficult natural and climatic conditions, that originates specific distinctions during the fulfilling of the diagnostic works.
Conception of the main gas transmission pipelines that is based on the determination of potential danger parts and individual inspection of each large-scale gas transmission pipeline has been presented in this work. Estimation procedure of flaw detection results with the purpose of operational capability prognostication of a gas transmission pipeline is also shown in this paper. The fields of application of the early and standard diagnostics are considered, and the analysis of possibility of inpipe and outpipe (from the ground) flaw detection is given in the conditions of Russia too. Practical samples of the diagnostics of gas transmission pipelines and technological equipment in several regions (Orenburg, West Siberia, Central Russia) are presented also.
Integrated inspection program of RAO “Gazprom” gas transmission pipelines is shown and the main procedures of its realization beginning since 1995 are given in this document.
Measuring Pipeline Movement in Geotechnically Unstable Areas Using an Inertial Geometry Pipeline Inspection Pig
Authors: Czyz Jaroslaw A. , Fraccaroli Constantino , Sergeant Alan P. 
Published: October 2016

NOWSCO’s Inertial Geometry Inspection system (GEOPIG) measures pipeline location coordinates (x,y,h) and provides data for measuring pipeline bending strain and strain changes used for structural analysis and integrity evaluation of pipeline systems in geotechnically unstable areas. This paper reviews the results of work to prove such a system’s accuracy and repeatability against deliberately induced strain events in a 26 inch operating gas pipeline.
An inertial geometry pipeline inspection tool provides nearly continuous measurement of pipeline centerline coordinates. Over time, run to run strain comparisons can be made providing information with respect to possible failure modes and timing.
Monitoring buried pipeline movements in geotechnically unstable areas using strain gauges and/or monitoring rods can provide incomplete information with regard to true pipeline movement due to the discrete, point type measurement of these systems. If movement occurs outside of areas where such monitoring systems are deployed, information regarding important pipeline strain changes can go unmeasured.
This paper reviews work involved in detecting, locating, and determining the magnitude and type of strain and corresponding pipeline movement induced at one unknown location within a 70 km section between two inertial geometry surveys. The inertial geometry results are compared against strain gauge field measurements.
Real Life Experience With Multipath Ultrasonic Gas Flow Meters
Authors: Sakariassen Reidar 
Published: October 2016

Multipath ultrasonic gas flow meters are to be considered as newcomers among flow meters for large, high pressure gas flows. Although the advantages of this type of meters are many and obvious, the metering community is still hesitating to go for it mainly because of lack of experience.
The objective of this paper is to present the experience of Statoil after more than six years experience with multipath ultrasonic gas flow meters. Our experience includes laboratory testing and operation in the field for a variety of designs and dimensions.
This paper presents the accuracy achieved by such meters including comparison between ultrasonic meters and orifice metering systems in operation, the unique possibilities that this type of meter offers for on-line verification of performance and installation effects.
Of particular interest should be noted that in the vicinity of low-noise control valves, such meters could stop functioning completely if no precautions are taken.
Natural Gas Transmission Opening Trade in Mexico: Energy and Environmental Benefits
Authors: Polanco Rene Perez , Rodriguez Betancourt Enrique 
Published: October 2016

This paper provides a summary of some management-technical changes and Pemex’s actions to face challenges derived from transportation, distribution, storage and marketing natural gas liberalization.
Since natural gas consumption hasn’t shown uniform growth for all consumer sectors, the Mexican Government decided to change the “rules of the game” to guarantee that such operations could attain the efficiency levels planned for 1995–2000. Thus, Constitutional Article 27 was reformed in 1995, the Energy Regulatory Commission and Natural Gas Regulation were created. This opened the doors to domestic and international investors to participate in transportation and distribution projects. So, to face this challenges and new missions, PGPB started working on new programs and projects to update it’s pipeline transmission system, such as risk management, operational reliability, quality systems, scada operation, reengineering business procedures and strategic planning to improve benefits and reduce incident/accidents. Finally, the energetic and environmental advantages of natural gas are addressed.
An Innovative Approach to Pipeline Isolation and Monitoring
Authors: Savard D. D. 
Published: October 2016

Pipeline companies continue to seek ways to improve the quality and efficiency of modifying and repairing pipelines. The focus is on improving the overall quality of the completed work, ensuring that all long term integrity issues are managed and that there will not be a need to return to the site. Many operators have found that when repairs or modifications were undertaken, failures occurred later causing environmental damage or situations where repeated work was required, both impacting landowners, public, customers and company profitability. Pipeline operators control and manage the construction of new pipelines to ensure that the highest quality standards are maintained. Over time these standards may be compromised due to the requirement for modifications and repairs.
Procedures must ensure that there is a proper balance between cost and quality, as in many instances these two areas are directly related to one another. There is a continued focus on reducing overall costs and the number of fittings that are left on the pipeline after repairs are completed. This, combined with the increased regulatory focus on pipeline safety will challenge the industry. Operators have found from experience that fittings are a known source of problems. Operators continue to modify work procedures to reduce the number of fittings that are left on the pipeline.
To date, reliability has been a major concern for operators when using internal pipeline isolation tools. The reliability of the first generation tools was compromised because they required large internal power sources, external controls and were very complex. With this new technology the reliability issue has been addressed.
A new technology has been developed that will allow an operator to carry out maintenance and repairs that will leave the pipeline in virtually the same state as new construction. The PAPlug (pressure activated plug) isolation tool is designed to allow operators to enhance the repair process while reducing over all costs. The development of the PAPlug focused on the use of a reliable energy source for setting and releasing the isolation tool. The energy source was found within the pipeline itself in form of pressure and flow.
The PAPlug has only three moving elements and is designed to be robust and reliable as there are no high maintenance seals, remote controls or large power requirements. All PAPlug operations use internal pipeline pressures which are readily available. The PAPlug can be operated multi-times per run allowing an operator to carry out a number of maintenance activities if required.
The PAPlug transmits internal pipeline pressures and/or temperature information to an above ground receiver allowing the operator to monitor status before and during isolation activities.
The PAPlug technology will allow the operator to select the optimum repair and modification process which include drain-up, pump around and nitrogen purge. The end result will be a repair that will leave the pipeline in new construction state.
Fatigue Curves for Damage Calculations for a Dented and Ovalled Section of the TransAlaska Pipeline System
Authors: Stevick Glen R. , Hart James D. , Flanders Bill 
Published: October 2016

During the summer of 1996, the TransAlaska Pipeline System (TAPS) experienced vibrations near Thompson Pass, about 25 miles north of Valdez, Alaska. The vibrations could, on occasion, be detected by residents living near the pipeline at the bottom of the pass. Close to the source of the phenomena, small bushes could be seen moving in response to the seismic shocks and a noise similar to a “mortar firing in the distance” could be heard. Alyeska Pipeline Service Company initiated an extensive investigation and quickly determined that the seismic shocks were a result of pressure pulses originating near the slackline-packline interface. This only occurred when the slackline-packline interface was positioned near a terraced portion of the pipeline topography on the downstream side of the pass. This knowledge allowed Alyeska Pipeline to control the pulsations by back pressuring the pipeline to move the slackline-packline interface well above the terrace location.
One key aspect of the project was an extensive analytical investigation of a dented and ovalled section of the pipeline near the origin of the pressure pulses. The main concern at this location was that, as each pressure pulse passes, the ovalled and dented pipe section tends to “reround” causing the pipe wall to flex a small amount. Since the pulses occurred frequently under certain flow conditions, there was a concern for possible fatigue damage to the pipe steel. The locations of maximum stress range were estimated to be near the 6:00 position on the outside surface of the pipe at the periphery of the dents in the X65 base metal (Stations 40959+28 and 40959+40 in Alyeska terminology).
This paper describes the “design” and “decision” S-N relationships that were developed during the Thompson Pass investigation to estimate fatigue damage. These curves are a combination of the AWS A fatigue curve and an adjusted version of the ASME Section VIII, Division 2 design fatigue curve. These curves were used together with a multi-axial fatigue model to compute fatigue damage due to pipe stresses caused by pressure pulse cycling as well as that due to operational startup and shutdown cycles.
Review and Proposed Improvement of a Failure Model for SCC of Pipelines
Authors: Jaske Carl E. , Beavers John A. 
Published: October 2016

Oil and gas pipelines are subject to stress corrosion cracking (SCC) in groundwater environments. Recent SCC failures have emphasized the need for accurate failure prediction models that can be used to assess the integrity and safety of existing pipelines. SCC is characterized by colonies of many longitudinal surface cracks in the body of the pipeline that link up to form long shallow flaws, with length-to-depth (L/d) ratios that are typically in the range of 50 to 200. Such flaws are particularly challenging for standard failure prediction models.
Because inelastic material behavior is usually associated with SCC failures of pipelines, the authors previously developed a failure prediction model that utilizes both flow strength and J fracture toughness to evaluate the failure of pipelines with crack-like flaws. Failure is predicted to occur either when the applied J value is equal to the J fracture toughness or the net-section stress is equal to the flow strength.
To improve the failure model, recent work has concentrated on long, deep surface cracks. Multiple surface cracks and their possible interaction also have been considered. Interactions are modeled for both flow strength and J fracture toughness failure criteria. Methods for evaluating crack interaction are proposed, and examples of crack-interaction predictions are presented. Also, existing methods for evaluating ductile tearing instability, as well as crack initiation toughness, are described. It is proposed that these methods will improve the failure model.
Comparison Between In-Line Crack Detection and Hydrostatic Testing in IPL’s Line 3
Authors: Gardiner Michael A. , Ward Clive R. , Miller Susan E. 
Published: October 2016

The BG Elastic Wave in-line crack detection vehicle was used to inspect 213.5 km (133 miles) of Interprovincial Pipe Line Inc’s (IPL’s) Line 3. Rigorous analysis of the inspection data, concentrated on the seam weld and surrounding region, identified 73 sites for excavation.
Pressure retaining sleeves were fitted at 17 locations. Of these, the most severe defect noted was a 25 mm (1 inch), 40% through wall long seam shrinkage crack. This was the only feature exceeding a size predicted to possibly fail under hydrotest to 100% SMYS. Twelve other cracks were sleeved, all of which were measured to be between 20% and 35% through wall.
Minor imperfections were found at the majority of those reported locations which were not sleeved.
Following completion of remedial work, 198 km (124 miles) of Line 3 was hydrostatically tested at pressures up to 100% SMYS, including 156 km (98 miles) that had been inspected by the Elastic Wave vehicle. There were no leaks or ruptures under hydrotest, demonstrating the ability of the tool to reliably detect cracks in the seam weld and surrounding region that were smaller than would have been found by hydrostatic testing alone.
Three Layer Epoxy/Polyethylene Side Extruded Coatings for Pipe for High Temperature Application
Authors: Alexander Mike 
Published: October 2016

The author will focus on the properties of three layer epoxy/ polyethylene coating for pipe, based on the experience developed in the lab, coating plant and in the field.
The demands of the respective Canadian and other international standards will be looked at with the purpose to evaluate respective merits of various specifications.
Special attention will be paid to the properties of the coating involving pipelines operating at elevated temperature, especially running through permanently wet areas, such as permafrost.
Lab results will be correlated with the real life experience.
Three layer Epoxy/ Polyethylene coatings will be compared to other commonly used coatings in the industry with the object to assess respective benefits and projected longevity versus cost.
Transition Temperature Determination for Thick Wall Line Pipe
Authors: Demofonti G. , Junker G. , Pistone V. , Junker Gerd , Pistone Valentino , Demofonti Giuseppe 
Published: October 2016

The applicability of Drop Weight Tear Test specimen to evaluate the ductile to brittle transition temperature of thick wall pipes (30 mm and 40 mm wall thickness) has been investigated by comparing West Jefferson tests at different temperatures and laboratory data.
The traditional API pressed notch specimen has been used with full and reduced thickness, together with chevron notch and weld notch starters. The different crack initiation methods have been examined with the goal of providing an easier test specimen, with reduced fracture energy.
The 85% shear area transition temperature indicated by the different test specimen show a reasonable similarity, but the higher costs of preparation of the alternative notch geometries limit their adequacy in substituting the traditional pressed notch specimen.
Good agreement has been found between standard DWTT specimen and full-scale test transition temperature. The results of this program together with literature data, confirm the validity of the DWTT specimen to measure the ductile to brittle transition temperature for thermomechanical rolled linepipe steels of thickness up to 40 mm.
The reduced thickness specimens conservatively predicted full scale behaviour.
Field Monitoring of Gases Using III-V Semiconductor Diode Laser Technology
Authors: Wang Hu , Hamp Michael J. , Cassidy Daniel T. , Nguyen An , Fritz Mark A. 
Published: October 2016

III-V semiconductor diode lasers can be used to make accurate measurements of the concentrations of gases. In this paper the field of trace gas detection using III-V semiconductor diode lasers will be reviewed with an emphasis on suitable applications of this technology in pipeline monitoring.
III-V semiconductor diode lasers emit light in the near infrared (NIR) with wavelengths ranging from 1 to 2 μm. Many molecules have absorption lines in this spectral range which makes them contenders for detection with diode laser technology. Molecules relevant to the pipeline industry that can be detected using diode laser systems include H2S, C2H4, C2H2, HF, CO2, CO, O2, NH3, HC1, NO, NO2, HCN, H2O and CH4.
Diode laser detection systems may be well suited for many pipeline related applications. Portable field-screening detection systems may be possible, such as hand-held systems which can be used to pinpoint leaks for compressor station inspection. Airborne (∼200 km/h) and mobile (∼40 km/h) systems which can be used for pipeline and urban area inspection may also be feasible. Stationary systems can be integrated into pipeline systems to provide real-time remote gas monitoring for Supervisory Control and Data Acquisition (SCADA) systems. Detection sensitivities of parts per million (ppm) or better are achievable for many gases. A single diode laser detector can be designed to detect more than one gas leading to versatile multipurpose systems. As III-V diode laser based gas detection systems exploit the same technologies as the highly successful telecommunications industry they have the potential to be low in cost, reliable, and easy to operate and maintain.
We will present an overview of state-of-the-art III-V diode laser detection systems. System performance will be evaluated and the usefulness of these types of detection systems will be demonstrated.
Support Operation and Monitoring Application of Pipeline Simulator (SMAPS)
Authors: Kondoh Hideki , Miura Kazuyoshi 
Published: October 2016

In 1994, Teikoku Oil Co., Ltd. (TOC) and NKK Corp. established a joint pilot project to provide pipeline application and evaluation of NKK’s gas hydraulic simulation engine (GASTRAN), and to co-develop a Demand Forecasting Model (DFC). When the pilot project finished in March 1997, a commercial system, Support Operation and Monitoring Application of Pipeline Simulator (SMAPS), was installed in TOC’s operation center.
SMAPS programs include a real time simulator, an off-line planning simulator, demand and supply database, SCADA interface program, and the DFC. The real-time simulator provides actual initial conditions to the off-line simulator. In addition, the demand and supply database facilitates inputting the data for each sales point and applying real time demand forecasts from DFC.
SMAPS has been mainly used to evaluate pipeline operation and monitor pipeline situations. Future plans include expanding usage for pipeline construction and maintenance and improving employee training.
SCADA Designs: The Evolution of the User Interface for the Pipeline Industry
Authors: Wagner Chad G. 
Published: October 2016

This paper will discuss some of the key features that have been implemented in the user interface component of IPL Energy’s Pipeline Control System (PCS).
IPL Energy operates the world’s largest crude oil and liquid pipeline system. In 1968, IPL Energy became one of the first pipeline companies in the world to implement computer based control of its pipeline systems, commonly referred to as SCADA (Supervisory Control And Data Acquisition). Since then, the SCADA system has been continually modified and improved in order to achieve high standards of reliability, safety, and operator functionality.
Unlike other SCADA systems, PCS has been developed from the ground up drawing from a wide range of experience and expertise in pipeline design, control, and operation. A brief overview of the past generations of SCADA systems will show how the user interface has evolved into the present system. The focus of the discussion will be on the Line Display, a single screen that can be used to operate a particular pipeline. The Line Display is the main operating screen used to control the pipeline and provides the operator with the current operating conditions, including operating pressures, pump statuses, and important alarms.
Field Performance and Surge Testing of Centrifugal Compressors
Authors: VanderSchee David A. 
Published: October 2016

In 1997 Alberta Natural Gas Co. Ltd (ANG) completed a field testing program of its centrifugal compressor fleet. Field performance and surge testing of centrifugal compressors in pipeline service was done for efficiency evaluation and to re-establish surge line control.
By confirming the actual location of the surge line, surge controllers are adjusted to allow a more efficient and greater operating range resulting in fuel savings and operating flexibility. The results of this testing provides an accurate operating window for the compression equipment which is then transferred to a hydraulic analysis computer model used to provide accurate capacity estimates in support of additional gas transmission contractible volumes. As part of the surge testing, suction to impeller eye differential pressure readings (used for surge control) were evaluated to determine strength, stability and repeatability. Finally, baseline data was established to determine current compressor operating efficiencies and will be used to determine future efficiency degradation.
ANG is a wholly owned subsidiary of TransCanada PipeLines, one of North America’s leading transporters of natural gas through its energy transmission businesses. ANG owns and operates the British Columbia segment of the Alberta-California pipeline system (ref Figure 1). Compression is provided at three compressor stations with eleven compressors totalling 187,000 installed ISO HP.
Pipeline Pumps for Energy Efficiency and High Reliability
Authors: Samarasekera H. , Lueneburg R. , Morton T. 
Published: October 2016

Key variables in the design of pipeline systems are pump efficiency, equipment reliability, and throughput flexibility since they significantly influence the pipeline operating costs.
Pumps commonly used in pipelines operate at high efficiency only at the Best Efficiency Point (BEP) capacity. Outside this capacity, efficiency decreases and the wasted energy is converted into harmful vibrations, noise and heat, contributing to premature pump failures. Conventional pumps do not provide capacity flexibility to a pipeline.
A horizontal split case pump with replaceable diffusers and capable of accommodating a series of impellers has been developed. An impeller/diffuser combination with a BEP capacity matching the pumping capacity is selected to maximise efficiency. Since it operates close to BEP capacity, minimal pump vibrations and noise improve pump reliability.
Hydraulic and mechanical design features of the pump, some concepts for the future and a discussion of the potential cost savings when used in pipeline systems are presented.