Low pulsation design of piping systems for high pressure reciprocating pumps

1996 ◽  
pp. 575-580 ◽  
Author(s):  
S. Notzon
Keyword(s):  
High Pressure ◽  
Piping Systems

State-of-the-art production processes for convoluted, corrosion-resistant, high-pressure oilfield pipework

2005 ◽  
Vol 219 (4) ◽  
pp. 345-355 ◽  
Author(s):  
G. J. Collie ◽  
I Black
Keyword(s):  
High Pressure ◽  
Shape Memory Polymer ◽  
Hot Isostatic Pressing ◽  
Current Application ◽  
Corrosion Resistant ◽  
Piping Systems ◽  
Corrosion Resistant Alloy ◽  
Plastic Liner ◽  
Welded Pipe ◽  
Hot Rolled

Currently, there are two widely used methods for manufacturing corrosion-resistant, high-pressure pipework for oilfield applications: fabrication of the pipework from several, separate overlaid components joined by welding, or by combining fabrication and induction bending. The former is expensive and time consuming. The latter is less expensive but there are restrictions on the bend radii that can be achieved. This paper considers a range of possible alternatives in the production of complex, corrosionresistant, high-pressure piping systems for oilfield equipment. Some of the options (hot-rolled and seam-welded pipe, explosion-bonded and seam-welded pipe, and bi-metallic extrusions) result in an end product that is broadly comparable with that produced by fabrication. Others (epoxy coating, shape memory polymer, preformed plastic liner, cured-in-place plastic liner, and liquid coating) do not provide a metallic coating but are used in similar applications in different industries. Finally, there are technologies (such as plating, hot isostatic pressing, ceramic lining, and vapour deposition) that are proven processes but have no current application that may be considered directly relevant to high-pressure piping systems. One new concept under development by the authors is introduced - the use of a thin-walled liner manufactured from a corrosion resistant alloy, and expanded into a prebent carbon steel pipe.

New Seismic Design Criteria of Piping Systems in High-Pressure Gas Facilities

2004 ◽  
Vol 126 (1) ◽  
pp. 9-17 ◽  
Author(s):  
Makoto Inaba ◽  
Masatoshi Ikeda ◽  
Nobuyuki Shimizu
Keyword(s):  
High Pressure ◽  
Seismic Performance ◽  
Seismic Design ◽  
Evaluation Method ◽  
Design Criteria ◽  
Ground Displacement ◽  
Piping Systems ◽  
Level 1 ◽  
Deformation Tests ◽  
Level 2

After the Great Hyogoken-nanbu Earthquake (1995), the Seismic Design Code for High-Pressure Gas Facilities of Japan was amended. This amended code requires two-step seismic assessments, that is, the evaluation of the Level 1 Required Seismic Performance for Level 1 earthquakes and that of the Level 2 Required Seismic Performance for Level 2 earthquakes. Seismic design of piping systems is newly included within the scope of the code. For Level 2 earthquakes, possible ground displacement due to liquefaction is taken into account. The evaluation method of the Level 1 Required Seismic Performance is specified in the amended code and that of the Level 2 Required Seismic Performance is proposed in the guideline. The evaluation of the former is based on elastic design and that of the latter on elastoplastic design. The propriety of the design criteria of piping systems with respect to ground displacement was confirmed by large deformation tests. In this paper, seismic design criteria of piping systems in the amended code and the evaluation method of the Level 2 Required Seismic Performance proposed in the guideline are introduced, and the results of the large deformation tests are reported.

General Considerations

2021 ◽  
pp. 11-15
Author(s):  
Charles Becht
Keyword(s):  
High Pressure ◽  
Elevated Temperature ◽  
High Purity ◽  
Normal Category ◽  
Piping Systems ◽  
Lower Hazard

The Code includes six categories of fluid service, which provides a means of discriminating among possible degrees of hazard. Less stringent design, examination, and testing are permitted for fluid service of lower hazard (Category D) and more stringent requirements are applied for more hazardous fluid service (Normal, Category M, Elevated Temperature and High Pressure). High Purity fluid service provides requirements needed for piping systems requiring a certain level of cleanness.

Acoustic Power and Acoustic Pressure in Piping Systems Handling High Velocity Steam and Gases Through a Pressure Reducing Device

2010 ◽  
Author(s):  
Frantisek L. Eisinger ◽  
Robert Sullivan
Keyword(s):  
High Pressure ◽  
Mach Number ◽  
High Velocity ◽  
Acoustic Pressure ◽  
High Capacity ◽  
Acoustic Power ◽  
Piping System ◽  
Hydrocarbon Gases ◽  
Piping Systems ◽  
Asme Paper

Piping systems handling high-pressure and high-velocity steam and various process and hydrocarbon gases through a pressure reducing device can produce severe vibration of the piping system and noise and pulsation in the surroundings. Utilizing the data published by Carucci, V.A., and Mueller, R.T., 1982, “Acoustically Induced Piping Vibration in High Capacity Pressure Reducing Systems”, ASME Paper No. 82-WA/PVP-8, we develop a relationship for acoustic power and acoustic pressure as a function of the product of the Mach number M and pressure drop Δp (MΔp) through the system. Thirty six cases were evaluated to formulate this relationship.

Mechanical Properties of Cold Worked Type 316L Stainless Steel in High Pressure Gaseous Hydrogen: Investigation of Materials Properties in High Pressure Gaseous Hydrogen—3

2007 ◽  
Author(s):  
Shinichi Ohmiya ◽  
Hideki Fujii
Keyword(s):  
Mechanical Properties ◽  
High Pressure ◽  
Stainless Steel ◽  
Room Temperature ◽  
Gaseous Hydrogen ◽  
Type Specimens ◽  
Type 316L ◽  
Piping Systems ◽  
Cold Worked ◽  
Pressure Hydrogen

Safety of on-board high-pressure hydrogen fuel tanks and piping systems in hydrogen refueling station is one of the most important subjects for upcoming hydrogen society featured by fuel cell vehicles. Type 316L austenitic stainless steel is known as a material in which the effect of hydrogen on mechanical properties is very small, so JIS SUS316L is recognized as the standard material for 35MPa type on-board fuel tank liner in the Japanese standard JARI-S001. However, solution treated 316L does not always have sufficient 0.2% proof stress, and materials having higher proof stress are strongly needed. One of the solutions is work-hardening of the material, which is conventionally used for piping systems for high pressure gas facilities. In this study, the effect of hydrogen on mechanical properties of 40% cold worked 316L in high-pressure gaseous hydrogen at 45MPa was investigated. Results are as follows: Any significant effect of hydrogen was not recognized in tensile tests using round bar type specimens at room temperature and 85°C. In axial fatigue life tests using sand glass type specimens (stress ratio R = −1) at room temperature, not so large difference was observed on S-N curves in air and in high pressure hydrogen. However, a little influence was observed in fatigue crack growth tests using half inch CT specimens at room temperature (R = 0.05). Microstructure observation reveals that any martensitic transformation did not occur. The degradation of fatigue crack growth rate in high pressure gaseous hydrogen is probably caused by the work hardened δ-ferrite which is generally contained in thick materials. However the effect of hydrogen is only limited and 40% cold worked type 316L stainless steel is considered to be used in high pressure hydrogen gas just like solution treated one.

Flow Induced Vibration Analysis of Topside Piping at High Pressure

2020 ◽  
Author(s):  
Paul R. Emmerson ◽  
Mike J. Lewis ◽  
Neil A. Barton ◽  
Steinar Orre ◽  
Knud Lunde
Keyword(s):  
High Pressure ◽  
Multiphase Flow ◽  
Low Pressure ◽  
Screening Methods ◽  
Flow Induced Vibration ◽  
Cfd Simulations ◽  
Forcing Function ◽  
Process Piping ◽  
Forcing Functions ◽  
Piping Systems

Abstract Flow induced vibration (FIV) from high velocity multiphase flow is a common source of vibration concern in process piping, potentially leading to fatigue failures and hydrocarbon leaks. FIV screening methods tend to be conservative for multiphase flows and are typically only validated for simple single bends at low pressure. FE can predict the response of a system if a sensible forcing function is provided. CFD can be used to predict realistic forcing functions in complex combinations of bends and tees, typically seen in process piping systems. FIV studies were performed on a topside production system operated by Equinor, carrying multiphase flow at high pressure (∼69 bara) conditions, where significant vibration was measured. The study assessed different vibration simulation methodologies, combining FE analysis with forcing functions based on both correlations and CFD simulations. The aim was to gain a better understanding of the accuracy and limitations of calculation methods typically used to assess fatigue. CFD simulations predicted similar force magnitudes but higher frequency forcing at 69 bara compared to equivalent simulations at atmospheric pressure (at the same liquid and gas superficial velocities). The forcing function correlations used do not predict higher frequency forcing at high pressure, which has a significant impact on the predicted vibration. Care is required when undertaking this type of analysis. It is important to have an accurate FE model of the as-built pipework and supports as well as a forcing function which accurately represents the fluid forces on the bends. For the case simulated here the magnitude and peak frequency of the forcing function had a significant influence on the response of the structure. Forcing functions based on correlated data from tests at low pressure should be used carefully for high pressure systems. In addition, the inclusion of phasing of the forces at each bend can influence the structural response, and simulations performed in the frequency domain do not consider this. A combination of CFD and FE modelling offers a potentially powerful tool for assessing and diagnosing multiphase FIV problems in hydrocarbon production piping systems.

A Practical Guide for Recognizing Elastic Follow-Up in Existing Power Piping Systems and Minimizing its Effects

2013 ◽  
Author(s):  
Lange Kimball
Keyword(s):  
High Pressure ◽  
High Energy ◽  
Point Of View ◽  
Repair Costs ◽  
Pressure Steam ◽  
Piping Systems ◽  
Safety And Reliability ◽  
Main Steam ◽  
High Temperature High Pressure

High temperature, high pressure steam piping can fail for many reasons. This can include some combination of metallurgical, operational, fabrication, erection and design short comings. This has proven that high-energy piping systems are not maintenance free and have a finite service life. From a safety and reliability point of view it is increasingly important to determine when this life is expended before failure occurs. This requires that conditions that can reduce life are recognized. Once recognized, it is equally important that these conditions be addressed in a manner that will help prevent personnel injury, forced outages and high repair costs. The ASME B31.1 Code states that piping is “subjected to strain concentrations due to elastic follow-up of the stiffer or lower stressed portions.” However, the phenomena of “elastic follow-up” is often overlooked in the design of creep prone piping such as main steam and hot reheat. It is also difficult to identify in the field. This paper addresses a methodology to recognize elastic follow-up in existing piping systems, possible consequences and the means to minimize its effect.

Static Testing High-Pressure Piping Components

1960 ◽  
Vol 82 (1) ◽  
pp. 15-22 ◽  
Author(s):  
T. G. Moore ◽  
E. J. Opersteny
Keyword(s):  
High Pressure ◽  
Safety Factor ◽  
Tube Wall ◽  
Strain Gages ◽  
Working Pressure ◽  
Exterior Surface ◽  
Static Testing ◽  
Wire Strain ◽  
Pressure Tubing ◽  
Piping Systems

A method for testing high-pressure piping systems for service in the 20,000 to 40,000-psi range is described. Tubing systems were pressure tested and their behavior followed by means of resistance-wire strain gages mounted on the exterior surface. A method is described for graphically determining the pressure at which a tube wall becomes fully plastic. The allowable working pressure of a tube is determined by applying a safety factor to this pressure. Tubing bends and fittings, including metal gaskets, flanges, and tees, are evaluated by comparing their behavior under pressure with that of the tube with which they are to be used.

Asset Integrity Management of High Pressure Piping Systems Subject to Creep

2013 ◽  
Author(s):  
Marvin J. Cohn
Keyword(s):  
High Pressure ◽  
Creep Damage ◽  
Condition Assessment ◽  
Management Program ◽  
Piping System ◽  
Original Design ◽  
Operation And Maintenance ◽  
Piping Systems ◽  
Integrity Management ◽  
Construction Operation

Safety and reliability are the preeminent concerns in the design, operation, and maintenance of power piping. Recent additions to the ASME B31.1 Power Piping Code (Code) have addressed condition assessment of covered piping systems (CPS). Mandatory requirements for the condition assessment of CPS are discussed in Chapter VII of the Code and nonmandatory guidelines are discussed in Appendix V of the Code. These documents discuss design, fabrication, construction, operation, and maintenance issues, and do not provide detailed guidance in the evaluation of high pressure piping systems subject to creep. An asset integrity management (AIM) program should integrate and consider all attributes that influence the intended function of the original design. In addition to the evaluation of specified design, fabrication, construction, operation, and maintenance issues, an asset integrity management program should also consider and evaluate significant time-dependent anomalies, such as flexible operation modes, malfunctioning supports, and creep redistributed stresses. An AIM program includes the identification of governing drivers that accelerate piping system damage and then develops countermeasures to mitigate or reduce the driving mechanisms. This paper discusses the large range of piping system stresses and the sensitivity of stress increase to 50% creep life reduction, indicating the need for a robust stress ranking methodology. The process results in an accurate selection of the most critical creep damage weldments for nondestructive examinations.

A New Seismic Design Criteria of Piping Systems in High Pressure Gas Facilities

2002 ◽  
Author(s):  
Makoto Inaba ◽  
Masatoshi Ikeda ◽  
Nobuyuki Shimizu ◽  
Tetsuya Watanabe
Keyword(s):  
High Pressure ◽  
Seismic Performance ◽  
Seismic Design ◽  
Evaluation Method ◽  
Design Criteria ◽  
Ground Displacement ◽  
Piping Systems ◽  
Level 1 ◽  
Deformation Tests ◽  
Level 2

After the Great Hyogoken-nanbu Earthquake, “Seismic Design Code for High Pressure Gas Facilities of Japan” was amended. This amended code requires two step seismic assessments, that is, evaluation of Level 1 Required Seismic Performance for Level 1 Earthquake and that of Level 2 Required Seismic Performance for Level 2 Earthquake. Seismic design of piping systems is newly involved in the scope of the code. For Level 2 Earthquake, possible ground displacement due to liquefaction is taken into account. When ground displacement occurs, foundations of structures settle, laterally move or incline as a conseqence, and a piping system supported by independent foundation structures suffers from relative displacements between supporting points, which may exceed several tens of centimeters. The evaluation method of Level 1 Required Seismic Performance is specified in the amended code and that of Level 2 Required Seismic Performance is proposed in the guideline. The former evaluation is based on elastic design and the latter on elasto-plastic design. The propriety of design criteria of piping systems against ground displacement was confirmed by large deformation tests. This paper introduces seismic design criteria of piping systems in the amended code and the evaluation method of Level 2 Required Seismic Performance proposed in the guideline, and also reports the results on the large deformation tests.

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