bluuebunny/crossref_metadata_2025_split huggingface dataset:
A Midstream Pipeline Operator’s Perspective on the Implementation of API 1183
Authors: Konell Jeremiah , Dedeke Brian , Hurst Chris , Wu Shanshan , Bratton Joseph 
Published: January 2021

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.
Returning Pipelines to Service Following a Mw7.5 Earthquake: Papua New Guinea Experience
Authors: Albrecht Robert , Birthwright Rhys-Sheffer , Calame John , Cloutier Justin , Gragg Michael 
Published: January 2021

Abstract
The Papua New Guinea Liquefied Natural Gas (PNG LNG) project is a joint venture with participation by ExxonMobil, Oil Search Limited (OSL), Kumul Petroleum, Santos, JX Nippon Oil and Gas Exploration and Mineral Resources Development Company, and began production in 2014. As described in a previous IPC paper, the project, operated by ExxonMobil PNG Limited (EMPNG) sustained a M7.5 earthquake and approximately 300 aftershocks in 2018, epicentered directly under key facilities. Around 150 km of high-pressure gas and condensate pipelines in the rugged PNG highlands were affected but did not lose containment or pressure. Immediately following the M7.5 event, EMPNG began efforts to assess and inspect the pipelines in order to ensure public safety, and, at the appropriate time, restore LNG production. The technical efforts took place along the pipeline Right of Way (ROW) in a remote jungle environment, which, following the earthquake, was also a disaster zone in which the few available resources were prioritized towards humanitarian relief. Due to resource constraints, the pipeline field inspection team typically numbered only two or three specialists.
The inspection team drew heavily on analysis work, ongoing since project startup in 2014 and in progress when the earthquake occurred, that simulated the condition of the ROW and pipe stress state following earthquake events similar in magnitude to what actually occurred. The body of existing analysis work allowed the field team to compare aerially observed ROW ground movements to previously modeled cases, and rapidly infer pipe stress state without actually measuring pipe deformation on the ground. Due to resource constraints, that latter activity, if required before startup, would have significantly delayed project restart. The worldwide network of technical resources that had been assisting with ongoing simulations was quickly re-directed to analyzing actual observed ground deformations, efficiently supporting the small field team from outside the disaster zone.
After restart, field inspection activities continued, observations were categorized, and an Earthquake Recovery (EQR) organization was initiated to execute ROW repairs. Just as the initial inspection work was aided by pre-earthquake analyses, EQR activities have been expedited by the extensive ROW maintenance program that had been ongoing prior to the earthquake.
This paper and accompanying oral presentation present details of the inspection and recovery, and show that the extensive simulations, preparations and maintenance programs supported by EMPNG during project operations prior to the earthquake enabled a rapid and efficient response when the earthquake actually occurred, and thus provided enormous value to the business.
The Impact of Pressure Fluctuations on the Early Onset of Stage II Growth of High pH Stress Corrosion Crack
Authors: Niazi Hamid , Zhang Hao , Lamborn Lyndon , Chen Weixing 
Published: January 2021

Abstract
Steel pipelines undergo the following sequential stages prior to high pH stress corrosion cracking (HpHSCC) failure, viz., formation of environmental condition, initiation of the intergranular cracks followed by cracks coalescence to form critical crack size (Stage I), mechanically dictated crack growth with higher rate (Stage II) compared to Stage I, rapid crack propagation to failure (Stage III). From fracture mechanics perspective, the crack size reaches the critical value at the onset of stage II; consequently, stress intensity factor (K) ahead of the crack tip exceed the critical value (KISCC). Although many researches have been devoted to understanding HpHSCC behavior, the mechanical conditions that accelerate the onset of stage II remains unknown. This study investigates the mechanical loading conditions that yield to early onset of stage II with respect to the most severe loading condition in operating pipeline, underload-minor-cycle type of pressure fluctuation. In this study, several loading scenarios were applied to pre-cracked CT specimens exposed to 1 N NaHCO3-1N Na2CO3 at 40° C and −590 mVSCE. The first series of tests were conducted through applying variable amplitude loading waveforms to determine the K value below the KISCC. It was observed the crack growth rate decreases from 1.5 × 10−7 mm/s to 2.5 × 10−8 mm/s when Kmax decreases from 36 to 15 MPa·m0.5. Then, both constant amplitude and variable amplitude loading scenarios with the Kmax = 15 MPa·m0.5 were applied to pre-cracked CT specimens. It was observed that low R-ratio constant amplitude cycles yield to highest crack growth rate (3.6 × 10−7 mm/s), which was one order of magnitude higher than other waveforms. However, comparing the intergranular crack advancement per block resulted in similar crack growth rates for those waveforms containing low R-ratio cycles. These results imply that stage I of crack growth is assisted by fatigue due to low R-ratio cycles. It was observed that loading/unloading frequency of low R-ratio cycles has a direct relation with crack growth rate at stage I, i.e., high frequency cycles accelerate onset of stage II. The implication of these results for pipeline operator is that pressure fluctuation, particularly large and rapid pressure fluctuation at the sites susceptible to HpHSCC, threatens the pipeline integrity. Avoiding such pressure fluctuations, if possible, increase pipeline lifespan and prevents catastrophic damages by intergranular stress corrosion crack growth through delaying the onset of stage II of HpHSCC crack growth.
Intelligent Prevention Method for Third-Party Damage of Long-Distance Pipeline Based on Mobile Devices Location Information
Authors: Ling Jiatong , Zhang Hang , Dong Shaohua , Luo Jinheng 
Published: January 2021

Abstract
As one of the main risks of long-distance oil and gas pipelines, the consequences of pipeline accidents caused by third-party damage (TPD) are usually catastrophic. At present, TPD prevention approaches mainly include manual line patrol, fiber-optical vibration warning, and unmanned aerial vehicle (UAV) line patrol, but there are some limitations such as untimely warning, false alarm, and the missed report. As the location technology of mobile device matures, the user group provides massive data sources for the collection of location information, with which the tracks and features of the third-party activity along the pipeline can be directly obtained. Therefore, this paper proposes a method to identify the TPD behavior based on the location data of mobile devices. Firstly, the characteristics of relevant destruction behaviors were extracted from the historical destruction events. Then, the location information of the third-party activity near the target pipeline is obtained and the data is processed to remove the influence of noise, to reduce the computational burden of the subsequent identification process. Finally, calculate the difference degree of neighborhood trajectory and the similarity with the TPD features based on the data feature grouping (Difference feature and Similarity feature) to classify the type of third-party activity. Taking a 10km pipeline segment as an example, the method of this paper is used to preprocess the collected data and calculate the difference degree and similarity, 232 suspected TPD events are identified. After the on-site verification of the suspected damage by the line patrol, the results show that the method can better identify the third-party activities near the pipeline.
Modeling of Advanced Ultrasonic Testing Methods for Improved Characterization of Pipeline Damage
Authors: Van Velsor Jason K. , Malinowski Owen M. , Riccardella Scott A. , Velandia Luis , Kania Richard 
Published: January 2021

Abstract
Characterizing the performance of nondestructive evaluation (NDE) methods for the in-ditch detection and characterization of stress corrosion cracking (SCC) and other damage types has proven challenging for several reasons. Firstly, the availability of pipeline samples with real damage is limited. Compounding this issue, real samples often need to be destructively evaluated to establish the true damage characteristics such that the performance of the NDE methods can be properly understood. Destructive testing is both costly and results in the loss of valuable test samples. Secondly, the actual application of NDE methods to real samples has been shown to have significant human performance variations, which are difficult to separate from technology performance. To address these challenges, this work reviews advanced ultrasonic NDE modeling tools that have been developed to assist in benchmark studies for characterizing crack-like defects, such as SCC, and for establishing best practices. Specifically, explicit/dynamic finite element modeling techniques are utilized to model and compare traditional phasedarray ultrasonic testing (PAUT) and the newer full-matrix capture (FMC) PAUT techniques, such as the total focusing method (TFM). Insights into performance levels of the different modeled approaches are reviewed and guidance on the optimal application of these approaches is discussed.
Reliability-Based Assessment Method of Buried Pipeline at Fault Crossings
Authors: Zheng Qian , Liu Xiaoben , Zhang Hong , Adeeb Samer 
Published: January 2021

Abstract
The tectonic fault, which is one of the most common geohazards in field, poses great threat to buried pipe segments. Pipes will process to buckling or fracture due to large strain induced by continuously increasing ground displacements during earthquakes. Therefore, it is imperative to conduct safety analysis on pipes which are buried in seismic areas for the sake of ensuring normal operation. However, the highly nonlinearity of pipe response restricts the proceeding of reliability assessment. In this study, a hybrid procedure combining finite element method and artificial neural network is proposed for reliability-based assessment. First of all, the finite element model is developed on ABAQUS platform to simulate pipe response to strike-slip fault displacements. Thus, the strain demand value (the peak strain value obtained by finite element model in each design case) can be collected for database establishment, which is the preparation for neural network training. Thoroughness of the strain demand database can be achieved by a fully comprehensive calculation with consideration of influencing factors involving pipe diameter and wall thickness, operating pressure, magnitude of fault displacement, intersection angle between pipeline and fault plane, and characteristic value of backfill mechanics. Sequentially, Back Propagation Neural Network (BPNN) with double hidden layers is trained based on the developed database, and the surrogate strain demand prediction model can be obtained after accuracy verification. Hence, the strain-based limit state function can be respectively determined for tensile and compressive conditions. The strain capacity term is simply assumed based on published papers, the strain demand term is naturally superseded by the surrogate BPNN model, and Monte Carlo Simulation is employed to compute the probability of failure (POF). At last, the workability of the proposed approach is tested by a case study in which basic variables are referred to the Second West-to-East natural gas transmission pipeline project. It indicates that ANN is a good solver for reliability problems with implicit limit state functions especially for highly nonlinear problems. The proposed method is capable of computing POFs, which is an exploratory application for reliability research on pipes withstanding fault displacement loads.
Case Study of “TIEAMM” Approach to Geohazard Identification, Characterization, and Mitigation
Authors: Nasrallah Joshua , Theriault Bailey , Kammereck Andreas 
Published: January 2021

Abstract
This study presents the implementation of a multidisciplinary team approach to geohazard identification, characterization, assessment, and mitigation \, that includes landslide subject matter experts (SMEs) in geotechnical and hydrotechnical engineering and geology and pipeline stress analysis with the pipeline owner/operator (Owner). This approach provided targeted and programmatic geohazard training, identification, exploration, assessment, mitigation, and monitoring, and hase been coin as the “TIEAMM” approach. The Owner worked with the geohazard SMEs to develop a system-wide geohazard pipeline integrity management program, including a phased geohazard assessment along the right-of-way, office and field-based training for the local operations staff, risk-based design mitigation approaches, on-site construction support, and continued monitoring.
The landslide discussed in this study is used as an example to demonstrate the TIEAMM approach; this site was identified by local operations staff, documenting differential movement of approximately 15 feet between November 2018 and February 2019. A more detailed geological exploration and assessment as well as a pipeline strain assessment was completed. The work allowed for mitigation efforts and corresponding costs to be optimized. The mitigation design was flexible to address ongoing monitoring, and then field-fit to address site conditions observed during the construction work. The approach to geohazard management completed for this site provided the data and information needed to make informed decisions to support targeted optimization for the scope and scale of mitigation work, and thereby avoided over-conservative (and thereby overly-costly) mitigation efforts.
Optimizing the Management of Excavation and Repair Data From Inline Inspection Programs
Authors: Safari Miaad , Shaw David 
Published: January 2021

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 Quantitative Index to Assess the Influence of Joint Fit-Up on Pipeline Weld Root Discontinuities
Authors: Grams M. R. , Ludwig L. , Mendez P. F. 
Published: January 2021

Abstract
Field experience on pipelines suggests that under the unique conditions of tie-in welding, a high-low offset at the inner pipe wall is related to an increased occurrence of latent root weld discontinuities such as cold cracking. Codes and standards offer conflicting and unclear guidelines regarding acceptance criteria for high-low offset. This study presents a numerical index to quantify the influence of non-ideal joint geometry on the latent discontinuity susceptibility of the root pass for circumferential pipeline welds. The index is based on the stress concentration at the root and the angular distortion associated with plastic strains produced during welding. This index relates geometric considerations such as pipe diameter, wall thickness, and the cross section of the root pass with welding procedure variables and the mechanical properties of the pipeline material. Although this study is meant for steel pipelines, the conclusions obtained are also applicable to other materials. The index presented is a contribution towards an objective criterion for acceptance of high-low offset during field welding, ranking the susceptibility to latent discontinuities as a function of variables available to practitioners during field welding.
Structured Response Plan After a Ground Movement Event
Authors: Wang Yong-Yi , Yu Dunji , Cook Mike 
Published: January 2021

Abstract
The vast majority of buried pipelines are not designed to accommodate significant localized ground movement caused by landslides, earthquakes, or subsidence/settlement. When a ground movement event occurs along the ROW of a buried pipeline, it is imperative that the pipeline operator determine whether the ground movement is a threat to pipeline integrity to protect those responding to the event, those living near the affected ROW, and the environment.
This paper covers the development of a response plan that provides guidance to pipeline operators responding to a ground movement event while considering the unique conditions associated with such events.
The response plan covers some critical decisions after an event, including, but not limited to (1) whether the event affects the pipeline, the local ROW, or those living adjacent to the ROW, (2) control of flow, i.e., the need for shutdown or pressure reduction, and (3) work needed to return the line to full-pressure service. The overall response plan is presented in three main phases:
• Phase 1: Immediate Response,
• Phase 2: Follow-on Assessment and Actions, and
• Phase 3: Long-term Management.
The structured response plan and associated guidance are presented in a self-contained stand-alone document available from PRCI. Parts of the document or the entire document can be adopted by operators, depending on the extent of existing procedures an operator may have. Alternatively, company-specific information and procedures can be added to the document to form a company-specific SOP.
Pipeline Multi-Parameter Decision Making Approaches
Authors: Abdolrazaghi Mona , Hassanien Sherif 
Published: January 2021

Abstract
Pipeline operators sometimes face challenges in finding an optimum decision while executing both capital and operational projects. Utility- and risk-based decision-making approaches could create a framework for devising an optimum solution, especially in cases involving multi-parameter decision making. From a utility function perspective, an optimum solution would be the one with the least amount of cost and the highest benefit. In other words, an optimum solution could be achieved by maximizing a utility function. Accordingly, as an optimization problem, constraints related to safety, risk, and reliability for a given scenario could limit or dictate the space of feasible solutions. Addressing the problem of arriving at an optimum solution for a multi-parameter decision is the core topic of this paper. Moreover, optimized utility functions — decision making analyses based on probabilistic risk assessment — are discussed. In addition, the paper introduces a conceptual approach that has been utilized for infrastructure decision making: the life quality index (LQI) approach.