AMPP Store - Products tagged with 'hydrogen sulfide'

ANSI/NACE MR0175-2021/ISO 15156:2020

Product Number: ANSI-NACE MR0175-2021

Publication Date: 2021

$420.00

Note: This document was originally published with errors in Table A.16, page 3-32. These identified errors are corrected. Errata sheet is included.

NACE MR0175/ISO 15156 gives requirements and recommendations for the selection and qualification of carbon and low-alloy steels, corrosion-resistant alloys, and other alloys for service in equipment used in oil and natural gas production and natural gas treatment plants in H2S-containing environments, whose failure could pose a risk to the health and safety of the public and personnel or to the equipment itself.

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ANSI/NACE MR0175-HD1998-SG Sulfide Stress Cracking Resistant Metallic Materials for Oilfield Equipment 1998

Product Number: 21302-HD1998

ISBN: 1-57590-021-1

Author: NACE International

Publication Date: 1998

$179.00

Metallic material requirements for resistance to sulfide stress cracking (SSC) for petroleum production, drilling, gathering and flowline equipment and field processing facilities to be used in H2S-bearing hydrocarbon service. Historical Documents 1998

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ANSI/NACE TM0284-2016, Evaluation of Pipeline and Pressure Vessel Steels for Resistance to Hydrogen-Induced Cracking

Product Number: 21215-SG

ISBN: 1-57590-163-3

Publication Date: 2016

$109.00

Test conditions for evaluation of pipeline and pressure vessel steels. Compares test results from different laboratories of the absorption of hydrogen generated by corrosion of steel in wet H2S.

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ANSI/NACE/ISO MR0103-HD2010, Materials Resistant to Sulfide Stress Cracking in Corrosive Petroleum Refining Environments

Product Number: 21305-HD2010

ISBN: 1-57590-168-4

Publication Date: 2010

$179.00

HISTORICAL DOCUMENT. This NACE Standard establishes material requirements for resistance to sulfide stress cracking (SSC) in sour refinery process environments, i.e., environments that contain wet hydrogen sulfide (H2S). It is intended to be used by refineries, equipment manufacturers, engineering contractors, and construction contractors.

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Chemical Resistance Of Epoxy Coatings In High Temperature And High Pressure And Aggressive Service Conditions.

Product Number: 51322-18028-SG

Author: Sudhir Ananthachar, Michael Cook

Publication Date: 2022

$20.00

The crude oil produced by fracking or hydraulic fracturing method are high in sulfur content (0.5%)1. The vast majority of vessels that are used in the petrochemical industry to store and transport materials are constructed using Carbon steel. Coating linings used for corrosion protection inside of vessels and tanks must perform under severe conditions such as an exposure to corrosive gasses ( H₂S) and carbon dioxide as well as high temperatures, high pressures and often must withstand the cold wall effect and rapid decompression.

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CO2 and the Partial Pressure Bandit

Product Number: 41216-984-SG

Author: James McDonald, Michael Harrison, Douglas Mittlesteadt

Publication Date: 2016

$20.00

Pressurized Atlas Cell Testing is commonly understood to be an aggressive accelerated test for lining systems due the combination of pressure, temperature and a thermal gradient across the coating film known as the Cold Wall Effect. This is especially true when Carbon Dioxide (CO2) is added to the gas phase, as CO2 is miscible with oil and soluble in water. A familiar gas mix of 5% CO2, 5% Hydrogen Sulfide (H2S), and 90% Methane (CH4) are used in test protocols to simulate head space conditions of tanks and pressure vessels in oil and gas production conditions.

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Comparison of Laboratory Based H2S Scavenger Methodologies for Oil and Gas Production

Product Number: 51321-16503-SG

Author: Jody Hoshowski/ Øystein Birketveit/ Aiman Kamaruzaman/ Alyn Jenkins/ Rachael Cole / Tore Nordvik

Publication Date: 2021

$20.00

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Concerns Over Utilizing Aluminium Anodes in Sealed Environments

Product Number: 51317--8956-SG

ISBN: 8956 2017 CP

Author: Alex Delwiche

Publication Date: 2017

$20.00

Seawater pH inside an offshore wind turbine monopole had changed from pH 8 to less than pH 5. And toxic gas alarms were energised. This paper discusses a theory why the pHdropped and solutions to overcome the low pH with the use of aluminium anodes.

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Corrosion and Corrosion Products in a Sour Environment from 80°C to 200°C

Product Number: 51317--9084-SG

ISBN: 9084 2017 CP

Author: Shujun Gao

Publication Date: 2017

$20.00

Corrosion rate of mild steel and character of corrosion products in sour environments at temperatures from 20 to 200°C. H2S-H2O water chemistry model was developed. Then, H2S corrosion tests were done at 80, 120, 160 & 200°C - exposure time of 4 days.

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Corrosion Control and Integrity Management of Flare Gas Recovery Units

Product Number: MECC23-20160-SG

Author: Mohamed M. Farah; Abdulaziz Al-Qahtani; Ibrahim Zahrani

Publication Date: 2023

$20.00

Gas flaring is often a frequent occurrence in the oil and gas industry, where significant unrecovered gas is flared to the atmosphere with wide ranging negative environmental implications such as increased greenhouse emission, and other pollutants that have negative health implications on local populations. However, recent environmental awareness, drive to lower emission and economic benefits associated with flare gas recovery has seen a shift in flaring practice. The recovery of flared gas reduces noise and thermal radiation, operating and maintenance costs, air pollution and gas emission and reduces fuel gas and steam consumption.

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Corrosion Control of Acid Flare Lines at Gas Treatment Facility

Product Number: MPWT19-15242

Author: Ibrahim Albrahim, Ricardo Costa, Jehad Al-Aithan, Maher Al-Abdullatif, Abdulaziz Al- Tijani

Publication Date: 2019

$0.00

In any operating facility, the integrity of flare or relief lines should always be closely maintained, as it is one of the most important safeguards during plant upsets or emergency conditions. The most common damage mechanism in acid flare lines is acid gas dew point corrosion”. Corrosion in such systems is often dependent on fluid stagnation, especially in the presence of acidic water, during idle conditions.
The intent of this paper is to shed light on the efforts done in a gas treatment facility to identify different root causes that impacted or accelerated Acid Gas Dew Point Corrosion. These included design deficiencies, equipment integrity, and process challenges. Moreover, the paper provides findings and recommendations to avoid the occurrence of similar events in acid flare lines.

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Corrosion Investigation Of Five Stainless Steels In Oil-Gas-Water Multiphase Flow Containing H2S, CO2 And Chloride

Product Number: 51322-18121-SG

Author: Peike Zhu, Honglan Zou, Qinghua Wang, Junzheng Yang, Yanzhao Yu

Publication Date: 2022

$20.00

M. B. Kermani pointed out that 25% of equipment failures in the oil and gas industry are caused by corrosion, and more than half of corrosion events are related to produced fluids containing CO₂ and H₂S. In recent years, the exploitation of sour oil and gas fields (containing H₂S or H₂S/CO₂ mixture) has become more and more common, and prominent problems such as tubing ruptures caused by pitting and uniform corrosion have appeared. In oil fields containing CO₂ and H₂S, local corrosion is a key factor restricting the selection of tubing and casing materials. In an oilfield containing CO2 and H2S in the Middle East, the authors corroded coupons on site, and carried out indoor simulation experiments for the problems found in the field test. The authors systematically studied 13Cr, S13Cr, 22Cr, 25Cr and 2550 in the presence of H₂S, CO₂ and high mineralization.

Products tagged with 'hydrogen sulfide'

Association for Materials Protection and Performance