Volume 2: Pipeline and Facilities Integrity最新文献

{"title":"Chasing Ghosts: An Integrative Approach to Properly Qualify a Pipeline Threat","authors":"Michael Turnquist","doi":"10.1115/ipc2022-87120","DOIUrl":"https://doi.org/10.1115/ipc2022-87120","url":null,"abstract":"\u0000 The execution of in-line inspection (ILI) as the primary assessment methodology to manage a specific pipeline integrity threat has become standard practice for pipeline operators. The ability for ILI to properly size and characterize pipeline anomalies is better than ever. However, there are challenges that operators should be aware of when it comes to understanding the limitations of ILI. These challenges can differ depending on the threat being managed.\u0000 The threat of cracking in a pipeline longitudinal seam weld can be particularly challenging to manage. Recent improvements in the detection capabilities of crack-detection ILI technology present a challenge for pipeline operators. It is not uncommon for ILI to report several hundred or even several thousand seam weld anomalies on a single pipeline. Managing this large number of features can be very difficult, and the repercussions of excavating features that do not pose a true integrity threat extend well beyond the financial. The elimination of unnecessary excavations will in turn decrease risk related to safety associated with every excavation and allow the operator to focus solely on the features that pose a true integrity threat.\u0000 This paper presents a case study in which a liquid pipeline operator was dealing with these exact challenges. A recent ultrasonic crack detection (UC) ILI reported several thousand linear longitudinal seam anomalies on a post-1980 vintage pipeline containing high-frequency electric resistance welded (HF-ERW) seams. To properly qualify the integrity threat, an integrated approach was executed that combined non-destructive evaluation (NDE), destructive material property testing, full-scale burst and fatigue testing, metallurgical analysis, raw ILI data review, and engineering critical assessment.\u0000 The results of the integrated testing and analysis identified that a large number of ILI-reported features were mis-characterized due to the presence of excessive internal trim associated with many of the seam welds contained in the pipeline. The analysis provided the necessary technical justification to forego excavations associated with the features that were mis-characterized by the ILI. Integrated testing and analysis provided the operator with a superior understanding of the true nature of the seam weld integrity threat for this pipeline.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"134306815","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Development of a Pressure Equipment Integrity Management Program in a Multi-Jurisdictional Liquids Pipeline Environment","authors":"Touqeer Sohail, Katarina Bohaichuk","doi":"10.1115/ipc2022-86901","DOIUrl":"https://doi.org/10.1115/ipc2022-86901","url":null,"abstract":"\u0000 Demonstrated public safety and environmental responsibility is key to the reputation and success of pipeline companies. This sentiment extends not only to pipelines themselves, but to all facility equipment as well. That is why Enbridge Liquid Pipelines (Enbridge) developed a Pressure Equipment Integrity Management Program that is designed to ensure the safety, integrity, compliance, and operational reliability of all pressure vessels and boilers in Enbridge’s liquid pipeline facilities.\u0000 A unique aspect of Enbridge’s Pressure Equipment Integrity Management Program is how it must identify and comply with regulatory requirements in a multitude of both federal and provincial/state jurisdictions in Canada and the United States. Depending on the type of pressure equipment and its location, it may be federally regulated, locally regulated, or potentially both if there is no clear delineation between regulatory authorities. These different requirements can be complex and difficult to follow for personnel tasked with maintaining pressure equipment integrity across the entire pipeline system.\u0000 This paper will describe how a liquids pipeline company can structure a successful Pressure Equipment Integrity Management Program that is entrenched in the overall company Integrity Management System. The program must utilize clear, effective, and action-based processes and procedures that identify and comply with multi-jurisdictional requirements and are based on industry best practices. Stakeholder responsibilities shall be clearly outlined as well as process steps and required actions to be taken to effectively manage hazards and risks and maintain compliance.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"27 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131883221","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Structured, Systematic Threat Based Approach to Evaluate and Improve Data Quality to Facilitate Digital Transformation","authors":"P. Tomar, Betsy Kruse, Samah Hasan, Sergiy Kondratyuk","doi":"10.1115/ipc2022-87872","DOIUrl":"https://doi.org/10.1115/ipc2022-87872","url":null,"abstract":"\u0000 Pipeline operators are rapidly and increasingly moving towards digital transformation in order to harvest efficiencies and achieve higher levels of reliability and safety. Fueled by advances in technology such as cloud computing and machine learning, data is considered a key asset, and pipeline operations are increasingly driven by information and analytics. However, successfully achieving a digital transformation toward reliable and high-quality data requires mature processes for obtaining, managing, evaluating, and continuously improving data quality.\u0000 During a review of pipeline risk assessment results, a pipeline operator (Operator) found that risk results for a particular pipeline were driven by the mainline coating type being listed as “un-coated.” However, further review of the records showed that the pipeline, in fact, was coated.\u0000 One of the Operator’s foundational principles is ‘data as an asset’. Thus, the Operator understands the critical impact of such data inconsistencies across many potential receptors, from financial impacts to public safety. Additionally, mature processes enhance confidence in prioritizing the “right work.”\u0000 Data quality is essential for the use of historical data, interoperability across various data systems, and generation of useful analytics. The data quality process maturity (Process maturity) evaluation aims to assess all processes, capabilities, and governance required for ensuring high data quality. As a result, the Operator decided to rigorously evaluate their data quality and the maturity of data quality processes.\u0000 The data quality assessment involved creating a comprehensive list of data elements required to assess a particular threat, prioritizing data elements, and documenting data storage by the source system. The data quality was then evaluated using Key Performance Indicators (KPIs), establishing a baseline.\u0000 An organization’s Process maturity varies from level one (Initial) to level five (Optimized). The Process maturity of the Operator was assessed on five evaluation areas: Governance, Organization & People, Data Standards, Requirements & Metrics, Process Efficiency, Technology & Tools. Results of the evaluation led to the identification of actionable gaps.\u0000 The process, as developed, leverages guidance provided in ISO (8000-8) [3] for data quality assessment and DNVGL-RP-0497 [4] for Process maturity evaluation. This paper presents a step-by-step approach developed for and successfully employed by the Operator as applied to pipeline integrity threats.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115281730","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Influence of Strain Hardening Model on the CorLAS™ Model for Cracked Pipelines","authors":"Xinfang Zhang, Meng Lin, Muntaseer Kainat, N. Yoosef-Ghodsi, J. Leung, S. Adeeb","doi":"10.1115/ipc2022-86856","DOIUrl":"https://doi.org/10.1115/ipc2022-86856","url":null,"abstract":"\u0000 Underground steel pipelines may experience failure due to the occurrence of cracks or crack-like anomalies as a result of internal and external factors such as manufacturing imperfection and geotechnical movement. Metallic materials like steel often undergo strain hardening as deformation increases. The strain hardening characteristics of materials are usually described by strain hardening models. Accurate approximations of the stress-strain curves are essential for numerical simulations. For pipelines containing longitudinally-oriented cracks, a software-based model often referred to as CorLAS™ is widely accepted and commonly used by the pipeline industry to estimate the failure pressures. In CorLAS™, the stress-strain behavior of pipeline steel is modeled based on a simple power-law relationship known as the Hollomon equation. However, the Hollomon model cannot characterize the full-range strain hardening behavior of metallic materials, which is an approximation by design. Additionally, the strain-hardening exponent, n, in the CorLAS™ model is estimated based on an expression using yield strength and ultimate tensile strength. By contrast, the n value in mathematical models such as the Ramberg-Osgood equation, Swift equation, Ludwik equation, Ludwigson equation can be evaluated by using curve-fitting regression techniques, i.e., fitting the experimental true stress versus true strain data to the empirical models. This paper reviews the most frequently used strain hardening formulas and explores the applicability and accuracy of these stress-strain models including the hardening exponent expression in CorLAS™ (Version 2). This is followed by a sensitivity study to investigate the effect of n on the failure pressure predicted by CorLAS™. The holistic accuracy of CorLAS in predicting burst pressure, compared to other widely accepted models, is not explored.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"121 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126773829","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Enhancement of Mechanical Damage Crack Evaluation","authors":"Arnav Rana, S. Tiku, M. Piazza, T. Burns","doi":"10.1115/ipc2022-87345","DOIUrl":"https://doi.org/10.1115/ipc2022-87345","url":null,"abstract":"\u0000 This paper presents the results of a project undertaken to enhance previously developed tools being adopted in an industry recommended practice (API RP 1183) for pipeline mechanical damage (MD) integrity assessment and management. This project builds on MD assessment and management tools, developed on behalf of Pipeline Research Council International (PRCI), Interstate Natural Gas Association of America (INGAA), Canadian Energy Pipeline Association (CEPA), American Petroleum Institute (API), other research organizations and individual pipeline operators and were included in API RP 1183. The specific tasks in the current project included the assessment and improvement of indentation crack formation strain estimation methods, evaluation of the impact of ILI measurement accuracy on dent integrity assessment, and level of conservatism (safety factor) inherent in different levels of dent fatigue life assessment incorporated in API 1183.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"283 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115822773","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Why and How of Data Integration for Integrity Management Pursuant to API TR 1178","authors":"Jackie Smith, Cesar Espinoza, K. Collins","doi":"10.1115/ipc2022-87064","DOIUrl":"https://doi.org/10.1115/ipc2022-87064","url":null,"abstract":"\u0000 Data integration is a foundational element and a regulatory requirement for pipeline operators as part of an Integrity Management (IM) program. Having taken effect in July 2020, the Pipeline Hazardous Materials and Safety Administration’s (PHMSA) new Gas Mega Rule heavily emphasizes the requirement for the validation of data and records. As a result, pipeline operators must face new challenges to ensure they are in continuous regulatory compliance. Data integration plays a major role in supporting pipeline operators and engineering consultants as they adjust to the new requirements set forth in regulations. The Integrity Management (IM) regulations require pipeline operators to include the results of the latest as well as of previous integrity evaluations, including risk assessment information based on integrated data from the entire pipeline. Leveraging this data and the analysis thereof is required when making decisions regarding the course of action to address pipeline threats.\u0000 The American Petroleum Institute (API) Technical Report (TR) 1178, “Integrity Data Management and Integration,” provides a compendium of systematic methodologies, recommendations and processes to spatially integrate and normalize integrity data to empower pipeline operators to efficiently analyze integrity-related data to support their integrity management decisions and programs. Through the execution of multiple post-ILI service projects, the significance of this TR has been realized as a cornerstone to support pipeline operators in their efforts to meet the requirements of new regulations and achieve compliance.\u0000 In the present case study, ILI results from various inspections gathered from over 179 post-ILI data integration projects for a mid-size pipeline operator located in the southern United States — totaling over 5,500 mi of pipe segments and ranging in diameter from 10″ to 24″ — were analyzed following the core processes described in API TR 1178. The datasets — ranging from hundreds to hundreds of thousands of integrity data records from different sources including a variety of in-line inspection (ILI) tool technologies and service providers — were interpreted to distinguish pipe features or references from anomalies. Subsequent analyses were applied to the integrated datasets and delivered per the pipeline operator’s specifications.\u0000 This effort greatly supported a seamless transition to achieve compliance with the new regulations and help to establish reporting requirements for technology and inspection service providers. The operator now has a complete historical ILI database. As it is fully integrated into the GIS system of record, the pipeline operator is able to transition into advanced analytics, helping them to spot trends and make sounder integrity management decisions long-term.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"126 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115403108","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Assessing Internal Pitting Corrosion With Encoded Ultrasonic Scanning","authors":"Joe Chen, Yanping Li, T. Place, Axel Aulin, Logan Galbraith","doi":"10.1115/ipc2022-86884","DOIUrl":"https://doi.org/10.1115/ipc2022-86884","url":null,"abstract":"\u0000 Internal corrosion is one of the main threats to pipeline integrity. For in-line inspection (ILI) based integrity programs, in-the-ditch non-destructive examination (NDE) data quality is imperative for ILI validation. NDE feature misclassification and/or depth inaccuracy can lead to unnecessary integrity actions such as unnecessary excavations, more frequent ILI, or increased risk to system integrity. Therefore, it is critical to ensure the accuracy of NDE data.\u0000 Ultrasonic Testing (UT) technology is the primary method to detect, characterize, and measure internal corrosion during in-ditch NDE. While studies have been conducted to understand various NDE technologies and capabilities associated with detecting, sizing, and classifying crack and external corrosion indications, less work has been published regarding field evaluation of internal corrosion indications.\u0000 In this study, real cases of liquid pipelines will be used to demonstrate the challenges in detecting, characterizing and sizing internal corrosion using current UT technologies. The cases show that improper NDE technique selection triggered additional excavations or caused internal corrosion to be non-conservatively under-reported. This work also includes various UT technologies, such as encoded zero-degree UT scanning, manual zero-degree UT testing, encoded Phased Array Ultrasonic Testing (PAUT), and Time of Flight Diffraction (TOFD) for characterizing and sizing both natural and machined defects in pipe and plate samples. High-resolution laser scans using Creaform HandyScan technology are used to verify actual feature depth. Depth sizing accuracy of each technology is established using statistical analysis. In order to determine detection limits of the above technologies, tests are performed on pitting and inclusion of various sizes, ranging from 8 mm to 0.5 mm in diameter.\u0000 This study will assist in establishing the limitations of current UT NDE technologies and recommendations to develop best practices for obtaining quality field NDE data from pipeline excavations for internal corrosion.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"259 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116456190","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Don’t Crack Up - Composite Repair of SSWC","authors":"David B. Futch, Christopher De Leon, Casey Whalen","doi":"10.1115/ipc2022-87288","DOIUrl":"https://doi.org/10.1115/ipc2022-87288","url":null,"abstract":"\u0000 Composite repairs have been extensively qualified and used to repair external corrosion and dents encountered on pipeline systems. More recently, test programs have explored extending the use of composite repairs to reinforce crack-like indications, including those found in low-frequency electric resistance welded (LF-ERW) pipe. This paper addresses repairing selective seam weld corrosion (SSWC) using composite repair systems, which is yet another extension for composite repairs. Current approved techniques for repair of SSWC include full encirclement steel sleeves and mechanical clamps, however, there can be challenges when repairing out of straight or out of round pipe and they can require large pipe excavations to find a suitable location for in-service welding. Finding a clean in-service welding landing zone becomes more difficult when considering vintage line pipe steel which have a higher probability of laminations.\u0000 SSWC results in a groove centered on the ERW bondline, which typically has lower toughness than the surrounding pipe. While corrosion is active, the groove remains relatively blunt. Therefore, a SSWC repair must minimize or eliminate the potential for sudden fracture along the seam. The chosen repair should reduce or eliminate the likelihood of crack formation at the stress concentration at the base of the SSWC groove.\u0000 In this study, fabricated SSWC-like features were reinforced with commercially available composite repair systems on vintage ERW pipe and subjected to cyclic pressure. Results have shown that composites can sufficiently reduce stress to prevent crack formation, providing a permanent repair option. Further corrosion is also mitigated by creating a barrier between the steel pipe and environment.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"34 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114460836","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Recoating SCC on Gas Pipelines Without Grinding","authors":"Ryan T. Milligan, Noelle Easter C. Co, M. Gao, R. Krishnamurthy, R. Kania, G. Roșca, Elvis Sanjuan","doi":"10.1115/ipc2022-87340","DOIUrl":"https://doi.org/10.1115/ipc2022-87340","url":null,"abstract":"\u0000 Considering both safety and cost-effectiveness in repairing SCC colonies, TC Energy and Blade Energy Partners conducted an engineering assessment to determine whether SCC colonies with depths of 20, 30, and 40%wt in base material and DSAW pipe can be left in a gas pipeline without grinding out provided that the fracture toughness and crack size conditions are met, and the features are recoated properly with a high-performance coating system. The operator would choose the safety level for recoating/grinding based on a fitness-for-service assessment. These findings are based on a literature review and verified by small- and full-scale testing. The product of the work is an assessment tool that identifies SCC cracks that are appropriate for recoating without grinding.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"15 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128508218","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental Study of Natural Gas Hydrate Formation Kinetics and Inhibition in Brine and Water","authors":"Farzan Sahari Moghaddam, M. Mahmoodi, Edison A. Sripal, M. Abdi, L. James","doi":"10.1115/ipc2022-88861","DOIUrl":"https://doi.org/10.1115/ipc2022-88861","url":null,"abstract":"\u0000 Hydrates formed under high pressure and low-temperature pipeline conditions are a serious flow assurance challenge. Furthermore, there are uncertainties with respect to the performance of different hydrate inhibitors based on their type, hydrocarbon and brine compositions, and operating conditions. Considering the inhibiting effect of salt ions in the brine composition can benefit hydrate chemical management strategies by reducing the high quantities of inhibitors.\u0000 This study experimentally evaluates the performance of kinetic and thermodynamic inhibitors and investigates the growth of hydrate under subsea pipeline pressure and temperature conditions. The effect of hydrate inhibitors was studied through a novel isothermal approach using varied brine compositions. Few studies such as Kakati et al. (2015) have focused on the inhibiting effect of multivalent ionic brine composition. Our study considers several multivalent ionic salts in formation brine and seawater including NaCl concentrations of 9.7 wt% and 2.4 wt%, compared to previous isochoric and isothermal studies relying only on one salt type. The influence of high and low salinity levels, including multivalent ionic salts, were evaluated, as they have been shown to be able to reduce the quantity of inhibitors used in hydrate chemical management strategies. The results were benchmarked against experiments using de-ionized (DI) water to capture the individual effect of the inhibitors and brine in inhibiting hydrate formation. Growth detection was also captured through image analysis to improve the understanding of hydrate kinetics in water and brine. The experimental results were evaluated according to hydrate equilibrium curves simulated using Calsep PVTsim Nova.\u0000 A novel macro scale isothermal approach was applied in PVT Cell to investigate natural hydrate formation and growth in DI water and brine systems. The ability of i) a kinetic hydrate inhibitor (KHI) and ii) methanol as a thermodynamic hydrate inhibitor (THI) to inhibit hydrate formation was studied. A sudden drop in the pressure (indirect measurement) confirmed through visual observations (direct measurement) is applied to identify the hydrate formation point.\u0000 Nine isothermal hydrate tests were conducted, with and without inhibitors, in DI water and brine systems. Results indicate that the KHI was best able to inhibit hydrate formation. KHI inhibited hydrate formation for more than 20 hours in the presence of formation brine at 4.8°C and 97 bar (>1400 psi). In the absence of an inhibitor, hydrate formation in water occurred during the pressurization step, at a pressure below 35 bar (500 psi). The hydrate mixture resulted in a sudden shift to darker colours upon formation, further grew, and agglomerated.","PeriodicalId":264830,"journal":{"name":"Volume 2: Pipeline and Facilities Integrity","volume":"80 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-09-26","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128871814","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}