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Metal Sulfide Scale Inhibitors

Product Number: 51320-14459-SG

Author: Konstantinos D. Demadis, Argyro Spinthaki, George Petratos, Juergen Matheis, Duygu Disci-Zayed, Wolfgang Hater

Publication Date: 2020

$20.00

Metal sulfide mineral scaling, fouling and deposition are frequently encountered problems in geothermal systems. Their formation, crystallization and deposition occur principally because of their extremely low solubility, based on the low solubility product (Ksp). Among the metal sulfides that cause problematic issues, the most common ones are iron sulfide (FeS), zinc sulfide (ZnS), lead sulfide (PbS), and, less frequently, antimony sulfide(s) (Sb2S3 and Sb2S5). Zinc sulfide, for example, has a Ksp of 2·10-25 mol²/L², whereas for PbS, it is 1·10-28 mol²/L² (~ three orders of magnitude less soluble). ZnS can precipitate either as Sphalerite or Zinc Blende, and PbS commonly crystallizes as Galena. Mitigation of such ZnS and PbS precipitates and deposits can be achieved by chemical interventions, by the addition of organic chemical additives to the water. Herein, we report the inhibitory effects of phosphonate-based chemical additives for ZnS and PbS scales. These additives can inhibit formation of sulfide scale, and, significantly, prevent its deposition on metal surfaces. The efficiency of these additives is dosage-dependent, and relatively high inhibitor concentrations are needed for their inhibitory activity to take place. Possible mechanisms will be discussed focusing on inhibition and dispersion.

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Metal, Moisture, and Mystery: The Curious Case of the Corroding Phone Charger Pin

Product Number: 51324-21155-SG

Author: Anil Kumar Chikkam; Mehrooz Zamanzadeh; Aaron Ulmer

Publication Date: 2024

$40.00

In metal-based electrical devices, corrosion poses a significant challenge and can be instigated by numerous factors such as moisture exposure, contact with salts and chemicals, and the occurrence of galvanic corrosion when different metals interact in an electrolyte-rich environment. Manufacturing defects, including substandard materials or insufficient protective coatings, can also contribute to corrosion. To combat this, it's essential to uphold cleanliness and dryness, conduct regular gentle cleaning to eradicate potential corrosive substances, and store the devices appropriately in cool, dry areas. The paper interestingly explores this phenomenon, with a case study focusing on the corrosion of a specific pin in a Phone charger as compared to the other seven pins on the same side of the charger.

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Metallic Film-Coated Optical Fiber Sensor For Corrosion Monitoring At High Pressures

Product Number: 51322-17804-SG

Author: Ruishu F. Wright, Paul R. Ohodnicki, Jr, Nathan Diemler, Margaret Ziomek-Moroz, John Baltrus, Michael Buric

Publication Date: 2022

$20.00

Corrosion is a common and critical issue in the oil and natural gas industry and it adversely affects the component functionality and structural integrity of infrastructure for exploration, production, transportation, processing, and CO2 sequestration. The natural gas delivery system includes 528,000 km (328,000 miles) of transmission and gathering pipelines in U.S. According to the Pipeline and Hazardous Materials Safety Administration (PHMSA) database, corrosion has caused ~25% of the natural gas transmission and gathering pipeline incidents over the last 30 years in the U.S., and 61% out of corrosion-caused incidents were due to internal corrosion.

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Metallizing Steel Bridges In New England - It’S Growing!

Product Number: 51322-17836-SG

Author: Jerry S. Zoller

Publication Date: 2022

$20.00

Bridge Owners are always on the lookout for a coating system for steel bridges that will perform for the longest time, and at a reasonable price. Metallizing has long been considered one of the best coating systems but the lack of qualified applicators simply has not made it available as an economical option. The success of early metallizing encouraged the investment in metallizing for Owners and bridge fabricators, and spurred on its significant growth over the past decade.

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Metallurgical Analysis of 30-Inch Pipe Containing an Internal Crack

Product Number: 51324-20700-SG

Author: Sudhakar Mahajanam; Chris Miller; Scott Harding; Sean Moran

Publication Date: 2024

$40.00

Pipeline defects are routinely found in the oil and gas industry. Most often they are minor, and do not affect the integrity and safety of the pipeline. However, in some cases, identifying and repairing critical defects is mandated to ensure long term integrity, which also entails choosing an appropriate repair technique. In this case study, we present a metallurgical examination of a 1949-vintage Grade X52 pipe containing an internal crack that was first identified at a client site. Laboratory examination confirmed that the feature was a pre-existing imperfection or defect, which had been weld repaired around the time of manufacturing or installation. Grinding marks and a distinct weld zone with three welding passes were observed in the region surrounding the crack. Scanning electron microscope (SEM) fractography of the crack surface indicated the presence of columnar grains close to the inside surface that are typical of a carbon steel weld. Energy dispersive x-ray spectroscopy (EDS) analysis indicated that the corrosion products consisted of iron

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Metallurgical and Micostructural Effect on CVN Impact Toughness in 2,25Cr1Mo Weld Metal

Product Number: MPWT19-15280

Author: Bertoni Dott, Markus Gustafson, Eva-Lena Bergquist

Publication Date: 2019

$0.00

2,25 Cr 1 Mo steel is required to comply with very stringent technical requirements when such a steel is applied in the Refinery Industry.Most of the attention is focused on the impact toughness performance of the weld metal which provides information on the structural stability of the pressure vessel taking into account the defect’s growth resistance in the welded joint.The assessment of welded joint toughness by performing CVN tests as a measure of this resistance remains the simplest and most widespread. Bainitic microstructure with very low ferrite content and small grain size of the primary austenite are effective in improving the CVN impact toughness at low temperature after min and max PWHT. The aforementioned microstructure is promoted by lowering the temperature of the Bs in addition to the heat input. Carbide precipitation at grain boundaries doesn’t significantly affect the impact properties of the weld metal after the industrial min and max PWHTs. The micro slag inclusions are investigated. Their chemical composition, volume and size is limited in the weld metal and they do not affect the CVN weld metal property. Min PWHT and max PWHT transform the Martensite/Austenite microstructure developed in the weld metal in as welded condition to Bainitic microstructure and the size and distribution of the carbide precipitated into the matrix. The PWHTs do not modify significantly the grain size of the microstructure which is mainly managed by chemistry and heat input. The type of current DC+ and AC significantly affect the chemistry of the weld metal providing different content of C, Mn, Si, Oxygen. Their contributions enhance the CVN impact properties especially when AC is used

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Metallurgical Aspects of HTHA in CS Below Traditional Nelson Curve Values

Product Number: 51320-15062-SG

Author: Jorge Hau

Publication Date: 2020

$20.00

High-Temperature Hydrogen Attack (HTHA) is a phenomenon that involves the formation and accumulation of methane (CH4) in steels operating under conditions where there is hydrogen ingress. To account for the phenomenon, it is necessary to know how the supply of solute carbon atoms occurs. What is discussed here concerns only low-carbon steel within the range 0.08-0.30 wt % carbon that has no intended additions of alloying element such as chromium (Cr) or molybdenum (Mo), and that it is typically delivered in the as-hot worked or normalized condition, resulting in microstructure consisting of pearlite colonies within a matrix of ferrite grains. Carbon steels do not normally contain carbon atoms in solid solution, but most are tied to cementite (Fe3C), except when retained in supersaturated solid solution by rapidly cooling from just below the subcritical temperature Ac1, 727 °C (1340 °F), in which case, the solute carbon atoms do not remain in supersaturated solution for long, they precipitate, but the resulting precipitates are rather unstable and get quickly thermally activated when heated to temperatures that are considered relatively too low to significantly affect the cementite in existing pearlite colonies. Thus, these precipitates may supply solute carbon atoms for HTHA damage to occur at temperatures that would not otherwise occur if there were only cementite in existing pearlite colonies.

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Metallurgical Investigation Of Hydrogen Reformer Tube Rupture – A Case Study

Product Number: 51323-18930-SG

$20.00

Hydrogen Reformer or so-called Steam Methane Reformer (SMR) is an important equipment to produce hydrogen or synthesis gas for refineries, petrochemical and fertilizer plants. It is basically a fired heater component that consists of four main sections which are radiant section, convection section, transition duct and stack.1 The configuration and general arrangement of SMR varies from different designers.

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Methodologies to Evaluate Corrosion of Carbon and Stainless Steels in Artificial Geothermal Solutions

Product Number: 51324-20716-SG

Author: Gabriela Aristia; Sabrina Marcelin; Nicolas Mary; Gaurav R. Joshi; Francois Grosjean

Publication Date: 2024

$40.00

Corrosion and scaling are some of the most common challenges in geothermal applications due to the complex brine chemistry combined with the high temperatures and pressures, and the gaseous components. To study mineral scaling at metallic surfaces, appropriate corrosion tests representing the real geothermal reservoir and operating conditions must be selected. This paper focus on the reconstruction of thermal gradients between geothermal fluids and the steel walls of wells and heat exchanger tubes, in laboratory and autoclave flow loop tests (up to 200°C and 300 bar), to simulate scaling and corrosion conditions. The implementation of an electrochemical measurement device makes it possible to monitor changes to the electrochemical behaviour of steel subjected to thermal gradients in these environments and so the corrosion response and in situ evolution of scales. Results from carbon steels (N80 and P110) and stainless steel (13Cr) in artificial geothermal brines representative of Dogger and Soultz geothermal wells in France are presented.

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Methodologies to Predict the Operational Limits of Nonmetallic Materials in Well Applications:The Cases of Hydrocarbon Production and Carbon Dioxide Sequestration

Product Number: MECC23-20049-SG

Author: Jushik Yun; Manuel Marya; Alireza Zolfaghari

Publication Date: 2023

$20.00

Nonmetallic materials (i.e., elastomers, plastics, and composites) are essential to transport and regulate flow of fluid from production sites to processing sites. In oil and gas production environments, the materials naturally encounter production liquids and gases, including natural gas (CH4, H2), crude oil, formation water, carbon dioxide (CO2), hydrogen sulfide (H2S), in addition to completion brines, organic/inorganic acids, and residual drilling muds. The selection of nonmetallic materials is critical to the structural integrity of oilfield equipment and the safety of rig workers not only in known notoriously hostile environments but also in regular oilfield operations and subsurface water and gas injection.

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Methodology Of Batch Inhibition Applied For TLC Mitigation

Product Number: 51321-16751-SG

Author: Mengqiu Pan; Maryam Eslami; Yuan Ding; Zineb Belarbi; David Young; Marc Singer

Publication Date: 2021

$20.00

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Methodology to Evaluate the Performance of Liquid Scavenger Application Technologies in Gas Pipelines

Product Number: 51323-19302-SG

Author: Jose Vera, Kyle Hilgefort

Publication Date: 2023

$20.00

Liquid H2S scavengers are sometimes injected into pipelines transporting wet gas to reduce the H2S concentration below allowable values before reaching certain points of the system. In these situations, the H2S scavenger injected into the pipeline should be able to reduce the H2S concentration in the gas to the target values within a given residence time.

The overall reaction kinetics when a liquid scavenger is directly injected into a wet gas pipeline can be separated in the following three steps, which have been described in previous publications:
Step 1: Transport of the liquid scavenger into the aqueous phase.
Step 2: Transport of H2S from the gas to the aqueous phases.
Step 3: Chemical reaction between the scavenger and dissolved H2S

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Association for Materials Protection and Performance