AMPP Store - Products tagged with 'hydrogen sulfide'

Available for download

Effect Of Varying H2S Content On High Temperature Corrosion Of Austenitic Alloys In A Pyrolysis Process Of Post-Consumer Plastics

Product Number: 51322-17552-SG

Author: Manuela Nimmervoll, Roland Haubner, Gregor Mori, Stefan Hönig

Publication Date: 2022

$20.00

Pyrolysis processes of post-consumer plastics are a promising chemical recycling route and a good alternative to disposal. Nevertheless, these processes are challenging for metallic materials since chlorine containing materials or biological components inside the feedstock can yield HCl and H2S, respectively, during cracking. In combination with high temperatures of the reactor zone metallic construction materials can be attacked by high-temperature corrosion.

Available for download

Electrochemical Investigation and Modeling of Cathodic Reactions on Iron Sulfides in Acidic Solutions

Product Number: 51323-19428-SG

Author: Payman Sharifi Abdar, Bruce Brown, Srdjan Nesic

Publication Date: 2023

$20.00

H2S corrosion, also known as sour corrosion, is a very serious type of metal degradation in oil and gas transmission pipelines. When H2S is present in an operating pipeline, localized corrosion is the type of attack which contributes to the most failures in oilfields, consequently, its impact on the economics of oil and gas production is indisputable. Therefore, mitigation of this type of corrosion could prevent such failures and significantly enhance asset integrity while reducing maintenance costs as well as eliminating environmental damage.

Available for download

Experimental Studies on the Stability of Highly Sour Corrosion Product Layers

Product Number: 51324-21028-SG

Author: Jon Kvarekvål ; Morten Tjelta

Publication Date: 2024

$40.00

The formation and long-term stability of corrosion product layers formed under sour service conditions with up to 30 bar H2S and 10 bar CO2 have been studied. Corrosion experiments were carried out in autoclaves with exposure times up to six months. The test solutions consisted of different brines with sodium chloride concentrations ranging from 0.1 g/L to 100 g/L. Temperatures were in the range of 15-120 oC. Both weight loss corrosion and localized corrosion data were obtained. 3D profilometry was used to obtain detailed data on pitting and localized corrosion morphology. The effects of the corrosion product layers, predominantly iron sulfides, on general and localized corrosion behavior are discussed on the background of existing literature.

Field Guide for Managing Iron Sulfide (Black Powder) within Pipelines or Processing Equipment”

Product Number: 37642-POD

ISBN: 978-1-57590-383-5

Author: Daniel E. Powell, Robert H. Winters, Mark A. Mercer

$190.00

This is a print-on-demand (POD) book that will be produced just for you in 2-5 days after your order. It should arrive at your door in about one to two weeks. However, due to supply chain and logistic challenges currently affecting the industry, it may take longer. Allow three weeks for international orders.

The Field Guide for Managing Iron Sulfide (Black Powder) within Pipelines or Processing Equipment offers practical guidance for corrosion control and operations personnel in managing black powder within their pipeline systems or processing equipment.

This book was written for new corrosion control professionals and operations personnel, who are based at production facilities. It provides straightforward, practical guidance regarding what is “black powder,” and why it may be a concern, field tests to be conducted, follow-up laboratory test that could be ordered, and an approach for using maintenance pigging, coupled with chemical treatments, to remove accumulations of “black powder.”

It begins with a discussion of what is black powder and identifies health and safety considerations associated with H₂S and the presence of black powder, identifying why there may be a concern.

The Field Guide presents field and laboratory tests typically used to identify the presence of iron sulfide, and then discusses maintenance pigging and/or chemical treatments for removing such particulates. Several case studies are also presented.

2019 NACE, 6 x 9" trim size, color, perfect bound, 264 pages

Field Guide for Managing Black Powder White Paper

Download the free white paper summary of this title to see specific areas of focus and discussion

Available for download

Field Guide for Managing Iron Sulfide within Pipelines or Processing Equipment

Product Number: 37642-pdf

ISBN: 978-1-57590-461-0

Author: Daniel E. Powell, Robert H. Winters, Mark A. Mercer

$190.00

The Field Guide for Managing Iron Sulfide (Black Powder) within Pipelines or Processing Equipment offers practical guidance for corrosion control and operations personnel in managing black powder within their pipeline systems or processing equipment.

This book was written for new corrosion control professionals and operations personnel, who are based at production facilities. It provides straightforward, practical guidance regarding what is “black powder,” and why it may be a concern, field tests to be conducted, follow-up laboratory test that could be ordered, and an approach for using maintenance pigging, coupled with chemical treatments, to remove accumulations of “black powder.”

It begins with a discussion of what is black powder and identifies health and safety considerations associated with H₂S and the presence of black powder, identifying why there may be a concern.

The Field Guide presents field and laboratory tests typically used to identify the presence of iron sulfide, and then discusses maintenance pigging and/or chemical treatments for removing such particulates. Several case studies are also presented.

Available for download

H2S Scavenger Laboratory Evaluation Based On Efficiency And Kinetics

Product Number: 51323-19316-SG

Author: Jose Vera, Zachary Berg, Nirmal Tatavalli-Mittadar, Richard Pollard

Publication Date: 2023

$20.00

The H2S concentration in produced fluids sometimes increases with time due to the phenomenon known as reservoir souring. This increase in H2S poses an integrity threat to downhole and topside oil and gas production facilities due to its impact in corrosion and environmental cracking susceptibility. Its concentration in natural gas is also limited to very low levels due to sales specifications.

Available for download

Highlighting Challenges with Corrosion Inhibitor Qualification Under High H2S, Sour Conditions

Product Number: 51323-19243-SG

Author: Hunter Thomson, Rodney Madjitey, Caroline Simpson, Dario M. Frigo, and Gordon Graham

Publication Date: 2023

$20.00

Corrosion and corrosion inhibitor qualification testing has been the subject of many publications over the years, with various guidelines and in-house protocols produced. This has led to a rather large set of test approaches for the qualification of corrosion inhibitors (CIs) for application in oil and gas production facilities.

For challenging conditions, including severe downhole conditions, final testing is often performed via specialized autoclaves or high-pressure flow loops to allow tests to be conducted under conditions as close to those pertaining in the field: T, P, pCO2 and pH2S (or more realistically, fugacity of CO2 and H2S), and as close as can be achieved to the field hydrodynamics.

Available for download

Impact of Novel Sulphidogenesis-Inhibitory Chemistries on Souring and MIC

Product Number: 51318-11183-SG

Author: Brett Geissler / Alicia Jones

Publication Date: 2018

$20.00

Microbiologically influenced corrosion (MIC) presents risk to operators and infrastructure in many industries. This work shows the continued potential of novel sulphidogenesis-inhibitory compounds and recent gains towards decreasing the impact of H2S production and on MIC.

Available for download

Incorporating Monte Carlo Analysis into a State-of-the-Art Corrosion Prediction System

Product Number: 51323-18910-SG

Author: Andrew Simm, Daniel Thomas, Gareth John, Steve Hodges

Publication Date: 2023

$20.00

Over the years there have been several different corrosion modelling software packages developed to provide predicted (estimated) corrosion rates for use in the oil & gas industries. Many are based on the original work of DeWaard & Milliams which provided a best-fit statistical model to corrosion rates measured in flow loop laboratory tests conducted at the IFE (Institutt For Energiteknikk) in Norway ; covering (initially) just partial pressure of CO2, temperature, liquid flow velocity and pH (typically as bicarbonate and dissolved CO2).

Available for download

Internal Corrosion of Flare Header - A Case Study

Product Number: 51324-21201-SG

Author: Ayman A. Alabdullatif; Lay Seong Teh; Hatam Mehraz; Anaam H. Shaikh Ali

Publication Date: 2024

$40.00

In a major gas-oil separation plant (GOSP) in Saudi Arabia, a major flare header suffered from severe internal corrosion. Upon analyzing the scale and sludge that was found accumulated in the line, a significant proportion of elemental sulfur was identified. This indicated that in addition to hydrogen sulfide and water (which were expected to be present in the line), significant amount of oxygen was also present. An investigation was conducted to identify the source of this oxygen and to eliminate it. Other critical factors that impacted the internal corrosion were also identified. The line was not properly sloped to drain accumulated moisture. Knock-out boot levels were often high and not regularly drained. In addition, purge gas was not operated at rates adequate to sweep any accumulated liquids. All of these factors combined led to an accelerated deterioration of the header.

Available for download

Interpreting H2S Scavenger Laboratory Test Results Using A Kinetic Model

Product Number: 51322-17844-SGG

Author: Jose Vera

Publication Date: 2022

$20.00

H₂S scavengers (SC) are commonly injected into multiphase pipelines transporting oil, water, and gas when the H₂S concentration is relatively low (ppm levels) but higher than the maximum allowable H₂S concentration in systems located downstream, due to integrity, safety or tariff limitations. Under these situations, it is expected that the H₂S scavenger injected in some points of the system (e.g., subsea) be capable of reducing the H₂S concentration before reaching certain parts of the system (e.g., topsides). In this case, the H₂S scavenger should be selected not only based on its capacity, but also on its kinetics at the expected field conditions.

Available for download

Laboratory experiments vs Field experience – Localized corrosion performance of lean duplex stainless steel UNS S32202 in municipal wastewater treatment plants

Product Number: 51323-19159-SG

Author: Audrey Allion, Charles David, Benoit Emo, Nicolas Larché

Publication Date: 2023

$20.00

Thanks to their good corrosion resistance and ease to shape and weld, austenitic stainless steel grades (e.g. UNS S31603) are used as standard materials for the construction of municipal wastewater treatment plants (WWTP). The main factors influencing the corrosiveness of the fluids in WWTP are halides concentration (more specifically chlorides), H2S content, low pH, temperature and their combined effects.

In municipal wastewater streams, chloride content, known to be one of the critical agents affecting the stability of protective passive layers for stainless steels2, is usually around 50-200 mg/L and in this content range does not present major issues for the austenitic grade.

Products tagged with 'hydrogen sulfide'

Association for Materials Protection and Performance