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Can Micelles Be Used To Expedite And Enhance Laboratory Qualification Testing?

Product Number: 51322-17824-SG

Author: Scott Rankin, Andy Osnowski, Emma Perfect

Publication Date: 2022

$20.00

The prevention of internal corrosion remains a significant challenge during the production of oil and gas. The use of film forming corrosion inhibitors is an important and cost-effective means of protecting assets from corrosion. These chemicals operate by forming a protective layer between the corrosive species present in the produced fluids and the pipe surface.

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Can Tarpaulin (TARP) Covering Protect Pipeline Coating FBE System 1a From UV Degradation?

Product Number: 51323-18938-SG

Author: Aissa VanDerVeen, Jeffrey Rogozinski, Thomas E. Grauer, Amal Al-Borno, Yuan Li, Moavin Islam, Ski Yin

Publication Date: 2023

$20.00

Fusion bonded epoxy (FBE) coated pipelines are extensively used throughout the world for transportation of various types of fluids and gases1. New and unused FBE coated pipes often end up being stockpiled in open yards for various reasons such as delay in start of a project, excess inventory etc. Outdoor exposure for long durations results in the physical and chemical degradation of the coating. This happens due to the interaction of the oxygen and moisture in the air, and the ultraviolet (UV) radiation from the sun which causes photo-oxidative degradation of the polymer in the coating.

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Carbonate And Sulfide Scale Formation In Multiphase Conditions

Product Number: 51322-17894-SG

Author: Olujide Sanni, Thibaut Charpentier, Anne Neville

Publication Date: 2022

$20.00

Inorganic fouling in oilfields has resulted in millions of dollars of operating expenditure every year since the inception of offshore oil and gas drilling, where mineral scale deposition in tubing, flowlines and downhole equipment leads to significant production downtime. Calcium carbonate (CaCO₃) fouling is endemic in oilfield systems, as produced water containing both bicarbonate and calcium ions is prone to form precipitates as a result of pressure changes during production.The release of carbon dioxide gas from the aqueous phase prompts the evolution of carbonate resulting in a rise in pH and consequent precipitation.

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Carbonation-Induced Corrosion Assessment for Reinforced Concrete Structures

Product Number: 51324-21169-SG

Author: Kingsley Lau; Samanbar Permeh; Sepehr Faridmarandi; Mansoureh Ghahfarokhi; Atorod Azizinamini

Publication Date: 2024

$40.00

Rebar corrosion induced by carbonation of concrete can occur in structures in both wet and dry exposures. This corrosion can become increasingly relevant in buildings as housing structures age and concrete carbonation occurs. The corrosion risk can vary depending on inter-related factors that include design, materials, and environmental exposure. The risk of corrosion furthermore can be assessed by the corrosion initiation and propagation phases. In this work two sets of testing were performed, including large scale concrete column testing to assess the corrosion behavior of steel subjected to loading and small-scale concrete testing to identify the effect of material and moisture condition environments on carbonation penetration. Concrete was cast with different water-to-cement ratio, limestone aggregate size, and conditioned in various moisture environments. The concrete specimens conditioned in wet conditions maintained in extended accelerated carbonation conditioning for up to 1 month of continuous carbonation of near 100% CO2 at 20 psi did not yield any significant carbonation penetration due to the slow rate of CO2 penetration. Concrete carbonation for the concrete specimens maintained in the dry condition fully carbonated within 67 hours and significant carbonation occurred for the concrete specimens maintained at 75%RH. In the carbonated concrete, the corrosion rate ranged from 0.2-0.8 µA/cm2. In presence of an external compressive force, the corrosion rates were similar; however, the time to corrosion initiation was delayed in time by a factor of 1.6-2. It is evident that both corrosion initiation and propagation should be considered when establishing recommendations for structural health monitoring and inspection.

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Case Analysis Of Electromagnetic Interference Of AC Substation On Pipeline

Product Number: 51322-17517-SG

Author: Su Jin

Publication Date: 2022

$20.00

A substation is a place where the power system converts voltage and current and receives and distributes electric energy. When a phase line is abnormally connected to another phase line or ground, a large amount of current will flow into the ground through the grounding bed of the substation. In such case, if metal structures exist such as buried pipelines near the substation, the pipelines often withstand serious electrical interference 1, which causes stray current corrosion of the pipelines 2 and other safety problems.

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Case Histories of Permian Area Scale Treatment Challenges and Chemical Program Optimization Strategies

Product Number: 51324-20857-SG

Author: Haiping Lu; Wei Wei; Chao Yan; Roy Young; David Nix

Publication Date: 2024

$40.00

During production in the Permian Area, one of the most impactful operational issues is scale formation and deposition, which can be related to CaCO3, CaSO4, BaSO4, FeS, etc. Scale can occur anywhere from downhole reservoirs and wellbores to topside facilities. Based on different scale formation species, operation conditions, and system requirements, scale treatment strategies will vary and can include the following aspects: • For downhole conditions, either continuous injection or squeeze application can be applied. Squeeze treatments can effectively prevent carbonate and sulfate scales for typically at least 6 to 12 months and help to reduce the amount of solid deposition downhole and in surface facilities. • For surface facilities, continuous injection is usually applied. Scale inhibitors should be compatible with high TDS & high calcium waters to avoid pseudo scale formation, causing increased usage of inhibitors and even blockage of the system. • Iron sulfide (FeS) scale can be controlled by chelators, i.e., Tetrakis(hydroxymethyl)phosphonium sulfate (THPS), though typically should be combined with corrosion control and even H2S scavenging treatment to reduce FeS solid deposition. This paper presents case histories from the Permian Area, including general scale issues, FeS deposition cases, and guidance for selecting suitable treatment programs to provide insights on future scale treatments in similar operations.

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Case History: Lining Water Box Condensers

Product Number: 51322-17937-SG

Author: Frank Rea

Publication Date: 2022

$20.00

An energy company hired a contractor to remove and replace the linings of water box condensers during a maintenance shut down. This case history will give a summary of the scope of work, a review of the specification, a description of the work performed, an accounting of the in-process inspection, and a summary of lessons learned during the project.

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Case Studies - Learnings from CUI Failures and Inspection Challenges

Product Number: 51324-21070-SG

Author: Ahmad Raza Khan Rana; J. Kyle Williams; Graham Brigham

Publication Date: 2024

$40.00

Corrosion under insulation (CUI) is a leading damage mechanism that affects the entire hydrocarbon sector, from production to oil refinery settings. Modern-day inspection programs for CUI management are prioritized based on the risk scores associated with assets. This study addresses the numerous field learning for CUI management from various standpoints. It discusses in detail the outlooks and pitfalls with various disciplines namely non-destructive examination (NDE), risk-based inspections (RBI), workmanship (i.e., insulation craft), field maintenance/ retrofitting as well as corrosion monitoring location (CML) ports. It also discusses some latest and novel remedies to address some CUI triggers and drivers.

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Case Studies on Application of Indirect Inspection Technology and Methodology in Municipal Water and Wastewater Systems

Product Number: 51324-21056-SG

Author: Vignesh Shankar; Emer Flounders

Publication Date: 2024

$40.00

Indirect inspection surveys have successfully inspected piggable and difficult to pig buried onshore Oil and Gas steel pipelines for decades. Indirect inspection methodologies such as ACVG, DCVG, CIS, GPS, leak detection, and DOC have aided oil and gas pipeline operators to monitor the health of their assets and completing mitigation to ensure their assets are functioning as per design, standards, and code. There has been extensive continuous improvement in monitoring oil and gas pipelines using indirect inspection technology. The water and wastewater pipelines have varying pipe materials. These pipelines are not regulated and do not have extensive literature, and dedicated teams to support maintaining assets in relation to external corrosion prevention, maintenance, and monitoring. This paper focuses on the application of demonstrated indirect inspection technology and methodology in municipal water and wastewater pipelines. The paper will discuss different pipe materials: coated steel pipeline, BWP, and PCCP inspected using indirect inspection technology, and present case studies.

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Case Studies On ECDA and SCCDA

Product Number: 51323-19231-SG

Author: Vignesh Shankar

Publication Date: 2023

$20.00

Pipelines have been considered one of the safest methods of transporting energy from one place to another. This is achieved through a systematically planned, documented, and comprehensive pipeline integrity management (PIM) program. PIM covers areas such as engineering, operations, inspections and maintenance, health and safety, and environment protection.

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Case Studies On Vapor Corrosion Inhibitor Monitoring Using Electrical Resistance Probes For Oil And Gas Assets.

Product Number: 51322-17855-SG

Author: Daniel Mugongo, Juan Dominguez Olivo

Publication Date: 2022

$20.00

Aboveground storage tanks (ASTs) are assets that contain valuable goods for the oil and gas industry. Consequently, monitoring and preventing loss of containment and extending the service life of those assets is a priority for the abovementioned industries. To monitor the degradation process of the tanks, ER probes are typically used to determine the corrosion rates. Corrosion rates can be used to forecast the service life of an asset by estimating the time at which the degradation reaches a critical thickness of the tank. If the corrosion rate is such that the critical thickness is expected to reach below the expected service life of the asset, the lifespan can be extended by corrosion mitigation methods.

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Case Study - DC Potential Influence Investigation via Waveform Analysis

Product Number: 51324-21149-SG

Author: Marc Blouin; Darrell Cornet

Publication Date: 2024

$40.00

While conducting overline surveys including Close Interval Survey (CIS), Alternating Current Voltage Gradient (ACVG), Direct Current Voltage Gradient (DCVG), Alternating Current Current Attenuation (ACCA) and Depth of Cover (DoC) in the Southeast Saskatchewan, Canada, a section of the cross Canada/US border Alliance pipeline, an unexpected CIS potential was encountered whereby potential measurements dipped, falling below the -850mV potential criteria, before rising again back into the range before the drop. The location of the potential drop occurred at a foreign crossing thus stray current was initially suspected. The field crew remained nearby while the foreign crossing owner representatives were notified of a possible interaction requiring further investigation. An interruption and influence analysis plan was put together to determine the nature of the influence on the Alliance DC Potential measurement circuit. This paper summarizes the preliminary analysis and test plan, the field measurements, and results.

AMPP Conference Papers

Association for Materials Protection and Performance