Field Performance and Surge Testing of Centrifugal Compressors

1998 ◽  
Author(s):  
David A. VanderSchee
Keyword(s):  
Natural Gas ◽  
Field Performance ◽  
Field Testing ◽  
Pipeline System ◽  
Centrifugal Compressors ◽  
Fuel Savings ◽  
Wholly Owned Subsidiary ◽  
Surge Control ◽  
Surge Line ◽  
Operating Window

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.

scholarly journals Centrifugal Compressor Testing Experience and Practice

1982 ◽  
Author(s):  
R. H. Meier ◽  
C. S. Rhea
Keyword(s):  
Natural Gas ◽  
Centrifugal Compressor ◽  
Performance Testing ◽  
Field Performance ◽  
Field Testing ◽  
Aerodynamic Performance ◽  
Reasonable Accuracy ◽  
Centrifugal Compressors ◽  
Factory Test ◽  
Different Types

Experience with factory and field performance testing of centrifugal compressors in natural gas service is presented. The ability of different types of factory test arrangements to closely predict future field performance is compared. Instrumentation requirements for achievement of reasonable accuracy in field testing are defined and discussed. Major aspects of mechanical and aerodynamic performance testing are addressed.

Comparative Analysis of Field Performance Testing in Centrifugal and Reciprocating Compressors

2009 ◽  
Author(s):  
Melissa Wilcox ◽  
Marybeth Nored ◽  
Klaus Brun ◽  
Rainer Kurz
Keyword(s):  
Uncertainty Analysis ◽  
Performance Testing ◽  
Field Performance ◽  
Field Testing ◽  
Test Methods ◽  
Operating Conditions ◽  
Reciprocating Compressor ◽  
Centrifugal Compressors ◽  
Test Environment ◽  
Test Uncertainty

Field testing of centrifugal compressors is often required by the operating company to determine compressor efficiency and power consumption over its speed range. Reciprocating compressors are also routinely tested to assure that adequate driver power is available and assess the losses associated with the compressor valves and pulsation controls. The uncertainties and test methods associated with field performance testing for these two compressors differ dramatically due to the field environment, unsteady flow field, and the traditional test methods used for compressor power. The field operating conditions, station piping and gas composition can influence the performance of both types but in different ways. Performance testing of a reciprocating compressor (typically based on pressure volume cards) differs dramatically from the more standardized approach to centrifugal compressor testing (based on enthalpy rise) mainly because of the effects of pulsating flow and the necessary volume bottles and pulsation filters in the reciprocating compressor installation. It is possible, however, to apply enthalpy rise methods to reciprocating compressor performance because the thermodynamic relationships still apply. In some cases, depending upon the influence of pulsations and the nozzle tap configuration, this measure of efficiency and power will introduce less uncertainty than measurements based on PV cards. Since the field test environment is less controlled than a manufacturer/third party test laboratory, uncertainty analysis must be used to validate or characterize the level of assurance in the measured performance. The uncertainty analysis can also provide an indication of the primary contributing measurements to an acceptably high uncertainty. For both reciprocating and centrifugal compressors, the uncertainty in the measured efficiency can be unacceptably high when some basic rules for proper test procedures and standards are violated. This paper presents an analysis of the requirements for proper field testing, examples of “near-ideal” test uncertainties for the two types of compressors and the primary causes of high test uncertainty in the field site test. These best practices are based on the recent industry guidelines published by the Gas Machinery Research Council (GMRC). Comparative illustrations are provided to highlight the differences in performance testing of centrifugal compressors and reciprocating compressor in terms of instrumentation, available test methods, and non-ideal effects on test uncertainty.

scholarly journals Operating Experiences of the First LM1600 Installation

1990 ◽  
Author(s):  
Ardean L. Braun ◽  
Stan R. Price
Keyword(s):  
Natural Gas ◽  
Performance Testing ◽  
Field Performance ◽  
Gas Pipeline ◽  
Pipeline System ◽  
Natural Gas Pipeline ◽  
Gas Generators

In the winter of 1988–1989, NOVA Corporation of Alberta commissioned three of the first GE LM1600 gas generators in turbine/compressor packages at compressor stations on its natural gas pipeline system. In the summer of 1989 a fourth unit was added at another station on the NOVA system. This paper describes the facilities in which the turbine/compressor packages were installed. In addition our experiences in commissioning, startup and operation will be discussed along with results of field performance testing.

Optimization of Operation Parameters for Direct Spring Loaded Pressure Relief Valve in a Pipeline System

2018 ◽  
Vol 140 (5) ◽  
Author(s):  
Hyunjun Kim ◽  
Sanghyun Kim ◽  
Youngman Kim ◽  
Jonghwan Kim
Keyword(s):  
Pressure Relief Valve ◽  
Pipeline System ◽  
Relief Valve ◽  
Pressure Relief ◽  
Computational Costs ◽  
Constant Degree ◽  
System A ◽  
Disk Mass ◽  
Analysis Scheme ◽  
Surge Control

A direct spring loaded pressure relief valve (DSLPRV) is an efficient hydraulic structure used to control a potential water hammer in pipeline systems. The optimization of a DSLPRV was explored to consider the instability issue of a valve disk and the surge control for a pipeline system. A surge analysis scheme, named the method of characteristics, was implemented into a multiple-objective genetic algorithm to determine the adjustable factors in the operation of the DSLPRV. The forward transient analysis and multi-objective optimization of adjustable factors, such as the spring constant, degree of precompression, and disk mass, showed substantial relaxation in the surge pressure and oscillation of valve disk in a hypothetical pipeline system. The results of the regression analysis of surge were compared with the optimization results to demonstrate the potential of the developed method to substantially reduce computational costs.

Integrity Assessment of Non-Piggable Pipeline Through Direct Assessment

2013 ◽  
Author(s):  
Jai Prakash Sah ◽  
Mohammad Tanweer Akhter
Keyword(s):  
Hydrostatic Pressure ◽  
Natural Gas ◽  
Stress Corrosion ◽  
Health Assessment ◽  
Assessment Method ◽  
Pipeline System ◽  
Internal Corrosion ◽  
Integrity Assessment ◽  
Direct Assessment ◽  
External Corrosion

Managing the integrity of pipeline system is the primary goal of every pipeline operator. To ensure the integrity of pipeline system, its health assessment is very important and critical for ensuring safety of environment, human resources and its assets. In long term, managing pipeline integrity is an investment to asset protection which ultimately results in cost saving. Typically, the health assessment to managing the integrity of pipeline system is a function of operational experience and corporate philosophy. There is no single approach that can provide the best solution for all pipeline system. Only a comprehensive, systematic and integrated integrity management program provides the means to improve the safety of pipeline systems. Such programme provides the information for an operator to effectively allocate resources for appropriate prevention, detection and mitigation activities that will result in improved safety and a reduction in the number of incidents. Presently GAIL (INDIA) LTD. is operating & maintaining approximately 10,000Kms of natural gas/RLNG/LPG pipeline and HVJ Pipeline is the largest pipeline network of India which transports more than 50% of total gas being consumed in this country. HVJ pipeline system consists of more than 4500 Kms of pipeline having diameter range from 04” to 48”, which consist of piggable as well as non-piggable pipeline. Though, lengthwise non-piggable pipeline is very less but their importance cannot be ignored in to the totality because of their critical nature. Typically, pipeline with small length & connected to dispatch terminal are non-piggable and these pipelines are used to feed the gas to the consumer. Today pipeline industries are having three different types of inspection techniques available for inspection of the pipeline. 1. Inline inspection 2. Hydrostatic pressure testing 3. Direct assessment (DA) Inline inspection is possible only for piggable pipeline i.e. pipeline with facilities of pig launching & receiving and hydrostatic pressure testing is not possible for the pipeline under continuous operation. Thus we are left with direct assessment method to assess health of the non-piggable pipelines. Basically, direct assessment is a structured multi-step evaluation method to examine and identify the potential problem areas relating to internal corrosion, external corrosion, and stress corrosion cracking using ICDA (Internal Corrosion Direct Assessment), ECDA (External Corrosion Direct Assessment) and SCCDA (Stress Corrosion Direct Assessment). All the above DA is four steps iterative method & consist of following steps; a. Pre assessment b. Indirect assessment c. Direct assessment d. Post assessment Considering the importance of non-piggable pipeline, integrity assessment of following non piggable pipeline has done through direct assessment method. 1. 30 inch dia pipeline of length 0.6 km and handling 18.4 MMSCMD of natural gas 2. 18 inch dia pipeline of length 3.65 km and handling 4.0 MMSCMD of natural gas 3. 12 inch dia pipeline of length 2.08 km and handling 3.4 MMSCMD of natural gas In addition to ICDA, ECDA & SCCDA, Long Range Ultrasonic Thickness (LRUT-a guided wave technology) has also been carried out to detect the metal loss at excavated locations observed by ICDA & ECDA. Direct assessment survey for above pipelines has been conducted and based on the survey; high consequence areas have been identified. All the high consequence area has been excavated and inspected. No appreciable corrosion and thickness loss have observed at any area. However, pipeline segments have been identified which are most vulnerable and may have corrosion in future.

Quantitative Risk Analysis and Comparison for Onshore and Offshore LNG Terminals: The Port of Suape - Brazil Case

2011 ◽  
Author(s):  
Marilia A. Ramos ◽  
Enrique L. Droguett ◽  
Marcelo R. Martins ◽  
Henrique P. Souza
Keyword(s):  
Natural Gas ◽  
Original Form ◽  
Pipeline System ◽  
Industrial Complex ◽  
Flammability Limits ◽  
Liquid Form ◽  
Worst Case ◽  
Final Destination ◽  
Natural Gas Pipeline ◽  
Vapor Cloud

In recent decades, natural gas has been gaining importance in world energy scene and established itself as an important source of energy. One of the biggest obstacles to increase the usage of natural gas is its transportation, mostly done in its liquid form, LNG – Liquefied Natural Gas, and storage. It involves the liquefaction of natural gas, transport by ship, its storage and subsequent regasification, in order to get natural gas in its original form and send it to the final destination through natural gas pipeline system. Nowadays, most terminals for receiving, storing and regasificating LNG, as well as sending-out natural gas are built onshore. These terminals, however, are normally built close to populated areas, where consuming centers can be found, creating safety risks to the population nearby. Apart from possible damages caused by its cryogenic temperatures, LNG spills are associated with hazards such as pool fires and ignition of drifting vapor clouds. Alternatively to onshore terminals, there are currently several offshore terminals projects in the world and some are already running. Today, Brazil owns two FSRU (Floating Storage and Regasification Unit) type offshore terminals, one in Guanabara Bay, Rio de Janeiro and the other in Pece´m, Ceara´, both contracted to PETROBRAS. The identification of the operation risks sources of LNG terminals onshore and offshore and its quantification through mathematical models can identify the most suitable terminal type for a particular location. In order to identify and compare the risks suggested by onshore and offshore LNG terminals, we have taken the example of the Suape Port and its Industrial Complex, located in Pernambuco, Brazil, which is a promising location for the installation of a LNG terminal. The present work has focused on calculating the distance to the LNG vapor cloud with the lower flammability limits (LFL), as well as thermal radiation emitted by pool fire, in case of a LNG spill from an onshore and from an offshore terminal. The calculation was made for both day and night periods, and for three types of events: operational accident, non-operational accident and worst case event, corresponding to a hole size of 0,75m, 1,5m e 5m, respectively. Even though the accidents that happen at an onshore terminal generate smaller vulnerability distances, according to the results it would not be desirable for the Suape Port, due to the location high density of industries and people working. Therefore, an offshore terminal would be more desirable, since it presents less risk to the surrounding populations, as well as for workers in this location.

Variable structure surge control for constant speed centrifugal compressors

2009 ◽  
Vol 17 (7) ◽  
pp. 815-833 ◽  
Author(s):  
Raef S. Shehata ◽  
Hussein A. Abdullah ◽  
Fayez F.G. Areed
Keyword(s):  
Variable Structure ◽  
Constant Speed ◽  
Centrifugal Compressors ◽  
Surge Control
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