Time-dependent economic risk analysis of the natural gas transmission pipeline system

2021 ◽  
Vol 146 ◽  
pp. 432-440
Author(s):  
Guoyun Shi ◽  
Weichao Yu ◽  
Kun Wang ◽  
Fuhua Dang ◽  
Jing Gong ◽  
...  
Keyword(s):  
Natural Gas ◽  
Risk Analysis ◽  
Time Dependent ◽  
Pipeline System ◽  
Economic Risk ◽  
Natural Gas Transmission ◽  
Transmission Pipeline

Data Analysis and Model Validation of Natural Gas Transmission Pipeline With Compressor Station

2019 ◽  
Vol 4 (3) ◽  
Author(s):  
David Cheng
Keyword(s):  
Performance Analysis ◽  
Natural Gas ◽  
Model Validation ◽  
Measurement Data ◽  
Gas Pipeline ◽  
Pipeline System ◽  
Actual System ◽  
Natural Gas Transmission ◽  
Transmission Pipeline ◽  
Performance Analysis Tools

Abstract Data from the distributed control system (DCS) or supervisory control and data acquisition (SCADA) system provide useful information critical to the evaluation of the performance and transportation efficiency of a gas pipeline system with compressor stations. The pipeline performance data provide correction factors for compressors as part of the operation optimization of natural gas transmission pipelines. This paper presents methods, procedures, and an example of model validation-based performance analysis of a gas pipeline based on actual system operational data. An analysis approach based on statistical methods is demonstrated with actual DCS gas pipeline measurement data. These methods offer practical ways to validate the pipeline hydraulics model using the DCS data. The validated models are then used as performance analysis tools in assessing the pipeline hydraulics parameters that influence the pressure drop in the pipeline such as corrosion (inside diameter change), roughness changes, or basic sediment and water deposition.

Gas Transmission Pipeline Safety and Integrity Activities and Results for INGAA Pipeline Companies

2012 ◽  
Author(s):  
Terry Boss ◽  
J. Kevin Wison ◽  
Charlie Childs ◽  
Bernie Selig
Keyword(s):  
Natural Gas ◽  
Management Practices ◽  
Pipeline System ◽  
Mandated Reporting ◽  
Pipeline Systems ◽  
Natural Gas Transmission ◽  
Transmission Pipeline ◽  
Integrity Management ◽  
Pipeline Safety ◽  
Transmission Pipelines

Interstate natural gas transmission pipelines have performed some standardized integrity management processes since the inception of ASME B3.18 in 1942. These standardized practices have been always preceded by new technology and individual company efforts to improve processes. These standardized practices have improved through the decades through newer consensus standard editions and the adoption of pipeline safety regulations (49 CFR Part 192). The Pipeline Safety Improvement Act which added to the list of these improved practices was passed at the end of 2002 and has been recently reaffirmed in January of 2012. The law applies to natural gas transmission pipeline companies and mandates additional practices that the pipeline operators must conduct to ensure the safety and integrity of natural gas pipelines with specific safety programs. Central to the 2002 Act is the requirement that pipeline operators implement an Integrity Management Program (IMP), which among other things requires operators to identify so-called High Consequence Areas (HCAs) on their systems, conduct risk analyses of these areas, and perform baseline integrity assessments and reassessments of each HCA, according to a prescribed schedule and using prescribed methods. The 2002 Act formalized, expanded and standardized the Integrity Management (IM) practices that individual operators had been conducting on their pipeline systems. The recently passed 2012 Pipeline Safety Act has expanded this effort to include measures to improve the integrity of the total transmission pipeline system. In December 2010, INGAA launched a voluntary initiative to enhance pipeline safety and communicate the results to stakeholders. The efforts are focused on analyzing data that measures the effectiveness of safety and integrity practices, detects successful practices, identifies opportunities for improvement, and further focuses our safety performance by developing an even more effective integrity management process. During 2011, a group chartered under the Integrity Management Continuous Improvement initiative(IMCI) identified information that may be useful in understanding the safety progress of the INGAA membership as they implemented their programs that were composed of the traditional safety practices under DOT Part 192, the PHMSA IMP regulations that were codified in 2004 and the individual operator voluntary programs. The paper provides a snapshot, above and beyond the typical PHMSA mandated reporting, of the results from the data collected and analyzed from this integrity management activity on 185,000 miles of natural gas transmission pipelines operated by interstate natural gas transmission pipelines. Natural gas transmission pipeline companies have made significant strides to improve their systems and the integrity and safety of their pipelines in and beyond HCAs. Our findings indicate that over the course of the data gathering period, pipeline operators’ efforts are shown to be effective and are resulting in improved pipeline integrity. Since the inception of the IMP and the expanded voluntary IM programs, the probability of leaks in the interstate natural gas transmission pipeline system continues on a downward slope, and the number of critical repairs being made to pipe segments that are being reassessed under integrity programs, both mandated and voluntary, are decreasing dramatically. Even with this progress, INGAA members committed in 2011 to embarking on a multi-year effort to expand the width and depth of integrity management practices on the interstate natural gas transmission pipeline systems. A key component of that extensive effort is to design metrics to measure the effectiveness to achieve the goals of that program. As such, this report documents the performance baseline before the implementation of the future program.

scholarly journals Virtual Pipeline System Testbed to Optimize the U.S. Natural Gas Transmission Pipeline System

2005 ◽  
Author(s):  
Kirby S. Chapman ◽  
Prakash Krishniswami ◽  
Virg Wallentine ◽  
Mohammed Abbaspour ◽  
Revathi Ranganathan ◽  
...  
Keyword(s):  
Natural Gas ◽  
Pipeline System ◽  
Natural Gas Transmission ◽  
Transmission Pipeline ◽  
The U.S

Pipeline Separation: A Review of Requirements, Guidance and Best Practices

2014 ◽  
Author(s):  
Danielle Demers ◽  
Arti Bhatia
Keyword(s):  
High Pressure ◽  
Natural Gas ◽  
Best Practices ◽  
High Energy ◽  
Separation Distance ◽  
Pipeline System ◽  
Buried Structures ◽  
Right Of Way ◽  
Natural Gas Transmission ◽  
Transmission Pipeline

Alliance Pipeline (Alliance), an integrated Canadian and U.S. high-pressure, high-energy natural gas transmission pipeline system, is committed to the development and application of best practices for the full lifecycle of its pipeline system. Currently, there are several publications which individually set out minimum pipeline separation requirements, and discuss considerations for establishing an appropriate separation distance between adjacent pipelines or other buried structures sharing the same right-of-way (RoW). Alliance has reviewed these existing publications, and has consolidated the requirements, guidance, and best practices discussed therein for application in its own company practices. This paper summarizes the review and consolidation of these requirements, guidance, and best practices.

scholarly journals Geologic Hazards Reconnaissance and Mitigation, and Implications to Natural Gas Pipeline Operations and Risk Management

1998 ◽  
Author(s):  
Jill Braun ◽  
Graeme Major ◽  
Michal Bukovansky ◽  
Donald O. West
Keyword(s):  
Natural Gas ◽  
Selection Process ◽  
Pipeline System ◽  
San Juan Basin ◽  
Natural Gas Pipeline ◽  
Significant Damage ◽  
Geologic Hazards ◽  
Natural Gas Transmission ◽  
Transmission Pipeline ◽  
Operation And Management

Northwest Pipeline Corporation (Northwest), a Williams Company, operates its 3,900-mile-plus natural gas transmission pipeline system in the northwestern United States. The system consists of a mainline (extending from the San Juan Basin in northwestern New Mexico to the U.S./Canadian border at Sumas, Washington) and numerous laterals that provide natural gas service to customers in six states. The original mainline was constructed in the mid-1950s, when the concern for, and the ability to identify geologic hazards as part of the alignment selection process was much more limited that today. As a result, the pipeline traverses extensive areas with pronounced exposure to numerous potential geologic hazards. A few of these hazards (particularly landsliding) have resulted in significant damage to, or rupture of the pipeline, which has typically been addressed by detailed investigations to characterize and mitigate the specific hazard. Methods have been developed and implemented over more than 15 years to identify and characterize the location, nature and magnitude of the geologic hazards, evaluate their effect(s) on the pipeline, and develop approaches to pipeline operation and management that can be used to mitigate the impacts of the hazards on the pipeline.

Integrity Assurance of Natural Gas Transmission Pipelines

1993 ◽  
Vol 46 (5) ◽  
pp. 146-150 ◽  
Author(s):  
G. J. Posakony
Keyword(s):  
Natural Gas ◽  
Preventive Maintenance ◽  
The United States ◽  
Direct Access ◽  
Pipeline System ◽  
Rehabilitation Programs ◽  
Natural Gas Transmission ◽  
Transmission Pipeline ◽  
Integrity Assurance ◽  
Transmission Pipelines

Natural gas transmission pipelines have proven to be a safe and efficient means for transporting the trillions of cubic feet of natural gas used annually in the United States. Since the peak of construction of these pipelines occurred between 1950 and the mid-1960s, their average age is now over thirty years. However, replacement of these pipelines because of age would be prohibitively expensive and unnecessary. Preventive maintenance and rehabilitation programs put into practice by the pipeline industry provides the key to ensuring the continued integrity of the transmission pipeline system. This article reviews the preventive maintenance practices commonly used by the gas industry. These practices include right-of-way patrols, corrosion control procedures, in-line inspection with intelligent or smart pigs that inspect the pipe while traveling through the inside of the pipe, direct access inspection of the pipe from bellhole excavations, and hydrostatic retesting of pipelines. When pipelines are properly maintained, these practices can ensure the integrity and long-term serviceability of transmission pipelines well into the 21st Century.

scholarly journals Data Analysis and Model Validation of Natural Gas Transmission Pipeline With Compressor Station

2019 ◽  
Author(s):  
David Cheng
Keyword(s):  
Performance Analysis ◽  
Natural Gas ◽  
Model Validation ◽  
Measurement Data ◽  
Real Life ◽  
Gas Pipeline ◽  
Physical Parameters ◽  
Pressure Drops ◽  
Natural Gas Transmission ◽  
Transmission Pipeline

Abstract Data from the DCS systems provides important information about the performance and transportation efficiency of a gas pipeline with compressor stations. The pipeline performance data provides correction factors for compressors as part of the operation optimization of natural gas transmission pipelines. This paper presents methods, procedure, and a real life example of model validation based performance analysis of gas pipeline. Statistic methods are demonstrated with real gas pipeline measurement data. The methods offer practical ways to validate the pipeline hydraulics model using the DCS data. The validated models are then used as performance analysis tools in evaluating the fundamental physical parameters and assessing the pipeline hydraulics conditions for potential issues influencing pressure drops in the pipeline such as corrosion (ID change), roughness changes, or BSW deposition.

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