Learnings From Data Management and Integration Efforts on the Enbridge Pipeline System

2004 ◽  
Author(s):  
Garry L. Sommer ◽  
Brad S. Smith
Keyword(s):  
Data Management ◽  
Management Program ◽  
Pipeline System ◽  
Data Set ◽  
Data Alignment ◽  
Commercial Market ◽  
History Of ◽  
Integrity Management ◽  
Management Effort ◽  
Analysis System

Enbridge Pipelines Inc. operates one of the longest and most complex pipeline systems in the world. A key aspect of the Enbridge Integrity Management Program (IMP) is the trending, analysis, and management of data collected from over 50 years of pipeline operations. This paper/presentation describes Enbridge’s challenges, learnings, processes, and innovations for meeting today’s increased data management/integration demands. While much has been written around the premise of data management/integration, and many software solutions are available in the commercial market, the greatest data management challenge for mature pipeline operators arises from the variability of data (variety of technologies, data capture methods, and data accuracy levels) collected over the operating history of the system. Ability to bring this variable data set together is substantially the most difficult aspect of a coordinated data management effort and is critical to the success of any such project. Failure to do this will result in lack of user confidence and inability to gain “buy-in” to new data management processes. In 2001 Enbridge began a series of initiatives to enhance data management and analysis. Central to this was the commitment to accurate geospatial alignment of integrity data. This paper/presentation describes Enbridge’s experience with development of custom software (Integrated Spatial Analysis System – ISAS) including critical learnings around a.) Data alignment efforts and b.) Significant efforts involved in development of an accurate pipe centreline. The paper/presentation will also describe co-incident data management programs that link to ISAS. This includes enhanced database functionality for excavation data and development of software to enable electronic transfer of data to this database. These tools were built to enable rapid transfer of field data and “real time” tool validation through automated unity plots of tool defect data vs. that measured in the field.

Optimizing Preventative and Mitigative Measure Selection

2016 ◽  
Author(s):  
Jeffrey Lachey ◽  
Keith Vanderlee ◽  
Robert Jewell ◽  
Tony Alfano
Keyword(s):  
Risk Assessment ◽  
Risk Management ◽  
High Risk ◽  
Management Program ◽  
Pipeline System ◽  
Subject Matter Experts ◽  
Data Alignment ◽  
Risk Management Program ◽  
Integrity Management ◽  
A Company

As risk assessment methodologies, tools, and processes continue to evolve in the industry, utilizing risk outputs to not only identify high risk locations, but to also understand the driver(s) behind the elevated risks for those locations is paramount. The ideal scenario for reducing pipeline risk is utilizing a risk-driven mitigation plan as this ensures the optimal use of company dollars, but also inherently means that a company has a firm understanding of their data and pipeline system. When the company understands their data and the implications for its inaccuracies, whether it be improper data alignment or incorrect application of data, they can effectively employ a campaign for preventative and mitigative measures (P&MM). However, if suspect data is used during a risk assessment, P&MM cannot accurately target risk drivers and high risk locations, making it challenging for the company to maximize their resources. For well over a year, an on-going partnership between AGL Resources Inc. (AGL) and Det Norske Veritas (U.S.A.), Inc. (DNV GL) has ensued to tailor a GIS-based risk management software solution for AGL. Through this collaboration among Integrity Management, Risk Management, IT, GIS, and Operations & Maintenance subject matter experts (SMEs) on both sides, one central hub of cross-functional pipeline knowledge was created. As a result, countless opportunities were exploited to identify supplementary data sources to employ new data manipulation techniques and processes, providing AGL with the foundation for such a risk-based Preventative & Mitigative Measure program. With the foundation laid and the proper risk elements present, AGL can now execute optimized risk-informed responses to identified high risk locations, pipeline segments, or pipeline systems. These optimized responses require an understanding of the types of P&MM available to reduce the threats and consequences, the costs involved for each P&MM implemented, and the utilization of a tool to allow various ‘what-if’ risk analyses to be conducted. Adopting and integrating this process as part of AGL’s risk management program allows them to capitalize on the maintenance dollars they spend while also reducing the potential hazards to the surrounding people, places and environment.

Testing of Acoustic Emission Technology to Detect Cracks and Corrosion in the Marine Environment

2010 ◽  
Vol 26 (02) ◽  
pp. 106-110
Author(s):  
Ge Wang ◽  
Michael Lee ◽  
Chris Serratella ◽  
Stanley Botten ◽  
Sam Ternowchek ◽  
...  
Keyword(s):  
Acoustic Emission ◽  
Structural Integrity ◽  
Pilot Project ◽  
Development Project ◽  
Management Program ◽  
Pipeline System ◽  
Inspection Planning ◽  
Structural Degradation ◽  
Integrity Management ◽  
Acoustic Emission Technology

Real-time monitoring and detection of structural degradation helps in capturing the structural conditions of ships. The latest nondestructive testing (NDT) and sensor technologies will potentially be integrated into future generations of the structural integrity management program. This paper reports on a joint development project between Alaska Tanker Company, American Bureau of Shipping (ABS), and MISTRAS. The pilot project examined the viability of acoustic emission technology as a screening tool for surveys and inspection planning. Specifically, testing took place on a 32-year-old double-hull Trans Alaska Pipeline System (TAPS) trade tanker. The test demonstrated the possibility of adapting this technology in the identification of critical spots on a tanker in order to target inspections. This targeting will focus surveys and inspections on suspected areas, thus increasing efficiency of detecting structural degradation. The test has the potential to introduce new inspection procedures as the project undertakes the first commercial testing of the latest acoustic emission technology during a tanker's voyage.

Hydrostatic Pressure Testing Program for a Liquid Petroleum Products Pipeline

1998 ◽  
Author(s):  
Robert V. Hadden ◽  
Kevin J. De Leenheer
Keyword(s):  
Water Treatment ◽  
Petroleum Products ◽  
Management Program ◽  
Pipeline System ◽  
Sewer System ◽  
Testing Program ◽  
Water Transportation ◽  
Pipe Line ◽  
Integrity Management ◽  
Products Pipeline

As part of its Integrity Management Program, Trans Mountain Pipe Line hydrostatically tests sections of its pipeline system with water transported to test sites through the pipeline. After completion of the testing, the water continues through the pipeline to a water treatment facility where it is treated and discharged to the municipal sewer system. Hydrostatic testing of an operating pipeline, although simple in concept, is a major undertaking. This paper will outline the technical aspects of Trans Mountain’s hydrostatic testing program including: test water transportation, environmental constraints, coordination of test activities and water treatment.

Integrity Management Program for Geo-Hazards in the OCENSA Pipeline System

2013 ◽  
Author(s):  
Hugo García ◽  
Carlos Nieves ◽  
Juan Diego Colonia
Keyword(s):  
Management Program ◽  
Andes Mountains ◽  
Pipeline System ◽  
The Andes ◽  
Oil Pipelines ◽  
Differential Settling ◽  
The Face ◽  
Integrity Management ◽  
The Caribbean ◽  
Geological Formations

Oil pipelines systems for hydrocarbons transportation are linear projects that can reach great lengths. For this reason, theirs paths may cross different geological formations, soil types, navigable or torrential waters; and they may face geotechnical and hydrological instability problems such as creeping slopes, geological faults, landslides, scour and differential settling which causes different relative movements between the soil and the pipeline. The OCENSA (Oleoducto Central S.A) 30″ and 36″ diameter system was built in 1997 to transport crude oil from the eastern foothills of the Andes to the Caribbean Coast along some 830 km of the Eastern Andes mountains range and the spurs of the central Andes mountains range of Colombia: it was a major challenge to secure the integrity of the pipeline in the face of natural events.

Optimizing the Management of Excavation and Repair Data From Inline Inspection Programs

2020 ◽  
Author(s):  
Miaad Safari ◽  
David Shaw
Keyword(s):  
Condition Monitoring ◽  
Data Gathering ◽  
Management Program ◽  
Data Uncertainty ◽  
Pipeline System ◽  
System Integrity ◽  
Integrity Management ◽  
External Corrosion ◽  
Inspection Data ◽  
Superior Approach

Abstract As integrity programs mature over the life of a pipeline, an increasing number of data points are collected from second, third, or further condition monitoring cycles. Types of data include Inline Inspection (ILI) or External Corrosion Direct Assessment (ECDA) inspection data, validation or remediation dig information, and records of various repairs that have been completed on the pipeline system. The diversity and massive quantity of this gathered data proposes a challenge to pipeline operators in managing and maintaining these data sets and records. The management of integrity data is a key element to a pipeline system Integrity Management Program (IMP) as per the CSA Z662[1]. One of the most critical integrity datasets is the repair information. Incorrect repair assignments on a pipeline can lead to duplicate unnecessary excavations in the best scenario and a pipeline failure in the worst scenario. Operators rely on various approaches to manage and assign repair data to ILIs such as historical records reviews, ILI-based repair assignments, or chainage-based repair assignments. However, these methods have significant gaps in efficiency and/or accuracy. Failure to adequately manage excavation and repair data can lead to increased costs due to repeated excavation of an anomaly, an increase in resources required to match historical information with new data, uncertainty in the effectiveness of previous repairs, and the possibility of incorrect assignment of repairs to unrepaired features. This paper describes the approach adopted by Enbridge Gas to track and maintain repairs, as a part of the Pipeline Risk and Integrity Management (PRIM) platform. This approach was designed to create a robust excavation and repair management framework, providing a robust system of data gathering and automation, while ensuring sufficient oversight by Integrity Engineers. Using this system, repairs are assigned to each feature in an excavation, not only to a certain chainage along the pipeline. Subsequently, when a new ILI results report is received, a process of “Repair Matching” is completed to assign preexisting repairs and assessments to the newly reported features at a feature level. This process is partially automated, whereby pre-determined box-to-box features matched between ILIs can auto-populate repairs for many of the repaired features. The proposed excavation management system would provide operators a superior approach to managing their repair history and projecting historical repairs and assessments onto new ILI reports, prior to assessing the ILI and issuing further digs on the pipeline. This optimized method has many advantages over the conventional repair management methods used in the industry. This method is best suited for operators that are embarking on their second or third condition monitoring cycle, with a moderate number of historical repairs.

A GIS-Based System to Assess the Environmental Consequence of a Liquid Pipeline Rupture at Watercourse Crossings

2012 ◽  
Author(s):  
Neil Ripley ◽  
Elisa Scordo ◽  
Alex Baumgard
Keyword(s):  
Initial Study ◽  
Management Program ◽  
Data Availability ◽  
Pipeline System ◽  
Vulnerability Factors ◽  
Environmental Consequence ◽  
Resource Limitations ◽  
Two Factors ◽  
Integrity Management ◽  
Socio Economic Factors

BGC Engineering Inc. (BGC) was retained by a large pipeline operator to develop a GIS-based system to assess and rank the environmental consequence of a pipeline rupture on watercourse crossings within their pipeline system. Several physical, biological and socio-economic factors contribute to the environmental consequence of a pipeline rupture on a watercourse. This study examined select spatial and vulnerability factors, and did not consider biologic or economic impacts. Three factors were selected as part of the initial study to prioritize the pipeline watercourse crossings according to: (1) size of the watercourse at the pipeline crossing, (2) proximity of each individual crossing to larger downstream watercourses, and (3) pipeline liquid flow rate volume. A spatial analysis was conducted to determine the first two factors, while input for the third factor was provided by the pipeline operator. Watercourse size was determined using Strahler’s stream order classification (Strahler 1952), while proximity to larger downstream watercourses was assessed using a Geographic Information System (GIS). This paper presents an overview of the data sources and methods used to develop an initial screening tool for identifying high consequence crossings within a pipeline system, and highlights the challenges encountered with acquiring and processing data to include in a consequence rating system. As with other pipeline risk assessments, the main challenges of this work include data availability, data integrity and resource limitations. This system is intended to fit within the pipeline operator’s current geohazard integrity management program and direct resources for a multi-year baseline field inspection program.

Enhanced Use of ILI Data to Improve Integrity Decisions

2012 ◽  
Author(s):  
Collin Taylor ◽  
Renkang Rain Zhu
Keyword(s):  
Metal Loss ◽  
Pipeline System ◽  
Precision Data ◽  
Data Alignment ◽  
Joint Characteristics ◽  
Tool Performance ◽  
Integrity Management ◽  
Data Improvement ◽  
Longitudinal Seam ◽  
Flux Leakage

With the current generation of in-line inspection (ILI) tools capable of recording terabytes of data per inspection and obtaining millimeter resolution on features, integrity sciences are becoming awash in a sea of data. However, without proper alignment and relationships, all this data can be at best noise and at worst lead to erroneous assumptions regarding the integrity of a pipeline system. This paper will explore the benefits of a statistical alignment method utilizing joint characteristics, such as length, long seam orientation (LSO), wall thickness (WT) and girth weld (GW) counts to ensure precision data alignment between ILI inspections. By leveraging the “fingerprint” like morphology of a pipeline system many improvements to data and records systems become possible including but not limited to: • Random ILI Tool performance errors can be detected and compensated for. • Repair history and other records become rapidly searchable. • New statistically accurate descriptions are created by leveraging the sensitivities of various ILI technologies. One area of material data improvement focused on within this paper relates to long seam type detection through ILI tools. Due to the differing threat susceptibility of various weld types, it is accordingly important to identify the long seam weld types for integrity management purposes. Construction records of older vintage lines do not always contain information down to the joint level; therefore, ILI tools may be leveraged to increase the accuracy of construction records down to this level. In this paper, the possibility of ILI tools, such as magnet flux leakage tools, ultrasonic crack tools, and ultrasonic metal loss tools, to distinguish different types of longitudinal seam welds is also discussed.

Applying Advanced Ultrasonic In-Line Inspection Technologies to Effectively Manage Hook Cracks

2020 ◽  
Author(s):  
Cory Wargacki ◽  
Wade Forshner ◽  
Rogelio Guajardo ◽  
Thomas Hennig
Keyword(s):  
Crack Detection ◽  
Crack Depth ◽  
Welding Process ◽  
Pipeline System ◽  
Data Set ◽  
Wide Range ◽  
Pipeline Segment ◽  
Integrity Management ◽  
Inspection Data ◽  
Pulse Echo

Abstract Axial cracking inspections have become common place on a global level within pipeline operator’s integrity management programs. As technology continues to improve, operators are presented with more accurate assessments of the assets that are in current operation. However as more information is collected more threats are being identified and need to be assessed in a manner that is more applicable to their specific morphology. It is well known that vintage ERW manufacturing techniques can suffer from a wide range of potential threats such as lack of fusion or inclusions within the steel forming hook cracks during the rolling and welding process. Current In-line inspection technologies that are designed to detect, Identify and size cracklike flaws in pipelines are very proficient at doing so. However, due to the physical principals of the Ultrasonic pulse echo technology, deep features approaching, or above pulse echo saturation amplitudes pose challenges in determining accurate depth sizing. In 2015 a Canadian pipeline operator determined the need to inspect one of their 16” assets for axial crack-like indications. During the analysis of this inspection data set, a number of saturated crack-like indications were reported. Saturated cracklike signals present a challenge to operators as they have to be considered in a conservative manner as 4mm or deeper which in turn leads to difficulties in the prioritization of resources associated with the excavation program. The operator approached NDT Global in 2017, after the release of NDT Global’s Enhanced sizing depth algorithm to reevaluate the features that were present in the previous crack inspection data set. Working together with the operator, NDT Global applied the Enhanced sizing methodology to all features of significance in the pipeline segment and compared the results to lab measurements and in field NDE measurements. The outcome of the reanalysis using the most up to date software algorithms utilizing enhanced sizing showed great benefits by increasing the accuracy of the crack depth sizing as NDT Global was now able to report full through wall depth sizing, however there were still some limitations on the ability to accurately size crack-like features as the primary threat is believed to be a result of hook cracks. As a final step in this program NDT Global was provided sample spools that were cut out of the pipeline segment to perform a pull testing campaign utilizing the newest crack detection technology that was specifically targeted towards accurately sizing tilted and skewed crack like features. The authors will briefly discuss the pipeline system and inspection campaign and in detail will discuss the benefits of using technology that has been developed to help pipeline operators better understand the threats in their integrity management program.

A Midstream Pipeline Operator’s Perspective on the Implementation of API 1183

2020 ◽  
Author(s):  
Jeremiah Konell ◽  
Brian Dedeke ◽  
Chris Hurst ◽  
Shanshan Wu ◽  
Joseph Bratton
Keyword(s):  
Selection Process ◽  
Management Program ◽  
Operating Conditions ◽  
Metal Loss ◽  
Pipeline System ◽  
Stress Risers ◽  
Integrity Management ◽  
Primary Focus ◽  
Condition Assessments ◽  
The Impact

Abstract In preparation for the upcoming (currently in draft form) Recommended Practice (RP) on Dent Assessment and Management (API 1183) [1], Explorer Pipeline Company, Inc. (Explorer) has performed an internal procedural review to determine how to effectively implement the methodologies into their Integrity Management Program (IMP). Explorer’s pipeline system transports hazardous liquids and is comprised of over 1,800 miles of pipeline ranging in diameter from 3 to 28 inches. The majority of the system was installed in the 1970s, but parts of the system were also installed as early as the 1940s. The primary focus of this review and implementation into the IMP is in regard to performing and responding to in-line inspection (ILI) based integrity assessments. Prior to the development of API 1183, dent assessment and management consisted of following a set of prescriptive condition assessments outlined in the Code of Federal Regulations (CFR) Title 49, Part 195.452. In order to do this, pipeline operators required basic information, such as dent depth, orientation, and interaction with potential stress risers such as metal loss, cracks, gouges, welds, etc. However, in order to fully implement API 1183, additional parameters are needed to define the dent shape, restraint condition, defect interaction, and pipeline operating conditions. Many new and necessary parameters were identified throughout the IMP, from the very initial pre-assessment stage (new ILI vendor requirements as part of the tool/vendor selection process) all the way to defining an appropriate reassessment interval (new process of analyzing dent fatigue life). This paper summarizes the parameters of API 1183 that were not part of Explorer’s current IMP. The parameters are identified, and comments are provided to rank the level of necessity from “must have” to “beneficial” (e.g. can sound and conservative assumptions be made when a parameter is not available). Comments are also provided to explain the impact of applying assumptions in place of parameters. The table of identified parameters should provide a useful tool for other pipeline operators who are considering implementing API 1183 as part of their overall IMP.

Total Pipeline Integrity Management System Implemented for KOC Pipelines: A Case Study

2010 ◽  
Author(s):  
M. Robb Isaac ◽  
Saleh Al-Sulaiman ◽  
Monty R. Martin ◽  
Sandeep Sharma
Keyword(s):  
Management System ◽  
Significant Loss ◽  
Management Program ◽  
Initial Assessment ◽  
Pipeline System ◽  
Transit System ◽  
Integrity Assessment ◽  
Wide Range ◽  
Integrity Management

In early 2005, Kuwait Oil Company (KOC) initiated a Total Pipeline Integrity Management System (TPIMS) implementation in order to carry out a major integrity assessment of its operating facilities, equipment, buried plant piping and pipeline network and to establish a continuing integrity management program. KOC Transit System is a complex infrastructure consisting of over three hundred pipelines, thousands of wellhead flow lines, and consumer and offshore lines for which there was a significant loss of data when the facilities were destroyed during a military invasion in 1990. An initial pipeline system assessment identified issues and actions regarding condition of the pipelines, corridors, requirements on in-line inspection (ILI), documentation, RISK assessment, status of international code compliance, and overall state of the system. Following recommendations from that initial assessment led to the development of a long term strategy; the execution of which required the implementation of a comprehensive integrity management program. This case study discusses the results obtained after five years of implementation of TPIMS at KOC. It will demonstrate some of the complex components involved in managing the integrity of the Transit System that have been made possible through the implementation of the system. The general concept and structure of TPIMS will be described, and how it deals with the complexity of the KOC pipeline system. The system made it possible to integrate and manage data from various sources, by conducting integrity assessment using ILI, Direct Assessment and hydrostatic testing, as well as structure a comprehensive RISK & Decision Support mechanism. This is one of the world’s first implementations of this magnitude which encompasses such a wide range of services and variables; all being managed in a single environment and utilized by a multitude of users in different areas at KOC. The biggest challenge in a project of this scope is data management. Examples will be shown of the integration structure to illustrate the benefits of using a single comprehensive and versatile platform to manage system requirements; ultimately providing system reliability and improving overall operational efficiency.

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