AMPP Store - Products tagged with 'h2s'

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Fast screening of Sulfide Stress Corrosion resistance of Supermartensitic Stainless Steel thought alternative test methods

Product Number: 51320-14577-SG

Author: Martien Duvall, Cécile Millet, Daniela Garcia, Guilaume Neel, Harold Evin

Publication Date: 2020

$20.00

In order to meet growing energy demand, oil and gas industries are facing many challenges, including the exploitation of increasingly deep fields with high pressure and high temperature in sour environments containing CO2 and H2S. Operators must carefully select materials that are resistant to these aggressive environments. The main risk associated with the use of martensitic stainless steels is the risk of sulfide stress cracking under well shut-in conditions.
The aim of this study is to evaluate the performance of supermartensitic stainless steels (13Cr-5Ni- 2Mo) based on NACE TM-0177-2016 method A and alternative methods such as slow strain rate test according to TM-0198-2016 and ripple strain rate test. Cyclic potentiodynamic polarization measurements were also performed to evaluate pitting and repassivation performance. The interest of this study is to present reliable and fast criteria to predict sulfide stress cracking performance of supermartensitic stainless steels through alternative methods. The effect of buffer and chloride content on pitting resistance and sulfide stress corrosion cracking resistance will also be discussed as well as the effect of Mo and Cr on pitting resistance.

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Fitness-for-Purpose Testing of UNS R30003, UNS R30035, UNS N07718 and UNS N09946 in Environment with H2S, CO2, and High-Chlorides

Product Number: 51324-20839-SG

Author: Noelle Easter C. Co; Ravi M. Krishnamurthy; Kenneth George; Bjørn-Andreas Hugaas; Ragnar Marcelius Fredriksen

Publication Date: 2024

$40.00

Critical equipment in high pressure high temperature (HPHT) oil and gas wells are commonly made of superalloys. Components in these wells require both high strength and corrosion resistance. In this study, four superalloys: Elgiloy (UNS R30003), MP35N (UNS R30035), Alloy 718 (UNS N07718) and 945X (UNS N09946) were tested in an environment with H2S, CO2, and high chlorides. Four-point bend tests were performed with N07718 and UNS N09946 materials while three-point bend tests were done on UNS R30003 and UNS R30035 in an autoclave with pH2S of 0.025 bar and pCO2 16.6 bar, and 308 g/L Cl- at 363°F for 30 days. Neither cracking nor pitting was observed on any of the four-point or three-point bend specimens. In addition to four-point bend testing, slow strain rate tests were performed on UNS N07718 and UNS N09946 materials. Results of the slow strain rate test showed no significant decrease in ductility in either UNS N09946 or UNS N07718. However, UNS N09946 performed better than UNS N07718 in a high chloride environment based solely on SSRT results.

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From Pits To Cracks: A Review Of 45-Years Of Published Research On Surface Trenches In Low Alloy Steels Exposed To H2S-Containing Environments

Product Number: 51322-17957-SG

Author: Dannisa R. Chalfoun, Teresa E. Perez, Mariano Iannuzzi, Mariano A. Kappes

Publication Date: 2022

$20.00

Carbon and low alloy steels (CS and LAS, respectively) used for exploration and production in the oil and gas (O&G) industry are normally exposed to environments that may contain H₂S in a wide range of concentrations. In aqueous solutions, H₂S acts as a cathodic poison.^1,2 A cathodic poison inhibits the recombination of atomic hydrogen to H₂, and as a result, favors its absorption by the metal.^1,2 In the presence of a susceptible microstructure and the simultaneous effect of applied or residual tensile stress, a crack can nucleate and propagate, when a critical concentration of hydrogen is reached in the metal.³ This environmentally assisted cracking (EAC) phenomenon is known as Sulfide Stress Cracking (SSC).² SSC is commonly addressed as a case of hydrogen embrittlement (HE) damage.²

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Guidelines for Using Water Analysis for Corrosion Prediction- Sampling Analysis and Data Interpretation

Product Number: 51323-19421-SG

Author: Y. Zheng, J. Sonke, B. Brown

Publication Date: 2023

$20.00

Various corrosion prediction tools for CO₂/H₂S corrosion have been developed in the past thirty years. For corrosion analysis in oil and gas production, the water chemistry largely determines the corrosion rate which is mainly driven by in-situ pH.

The in-situ water or brine is pressurized with acid gases (CO₂/H₂S) which results in a decrease in pH and typically an increase in the corrosion rate.

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H2S, CO2 and High Chloride Downhole Environment Modelling and Fitness for Purpose Testing of UNS S39274, UNS N08535 and UNS N06255 Corrosion Resistant Alloys

Product Number: 51324-20838-SG

Author: Noelle Easter C. Co; Ravi M. Krishnamurthy; Kenneth George; Bjørn-Andreas Hugaas; Ragnar Marcelius Fredriksen

Publication Date: 2024

$40.00

Aker BP is planning to drill four high-pressure, high-temperature wells in a gas field. The produced fluids are primarily composed of gas condensate with formation water. The operator anticipates a chloride environment greater than 120,000 mg/L in these four wells. ISO 15156 specifies a chloride limit of 120,000 mg/L for super duplex alloys for downhole applications. The objectives of this study are to determine the chemistry inside these four wells, to identify the test parameters representative of the downhole environment, and to assess if UNS S39274, UNS N08535 and UNS N06255 are suitable tubing materials. Thermodynamic modeling based on the anticipated production rate from each well was employed for the determination of downhole chemistry. Results show that chloride concentration can reach 308,000 mg/L. Scaling of halite, barite, calcite, and aragonite was also predicted to occur at certain depths inside the well. The parameters used for fitness-for-purpose testing were selected based on chloride conditions with and without halite scaling. The performance of UNS S39274, UNS N08535 and UNS N06255 was assessed using four-point bend tests, crevice corrosion tests, and slow strain rate tests in the simulated downhole environment with 0.025 bar pH2S, 16.6 bar pCO2 and high chloride concentration. No cracking was observed on UNS S39274 and UNS N06255 four-point bend specimens. However, one out of twelve UNS N08535 specimens tested exhibited a crack at a location outside the inner roller of the four-point bend jig. The corrosion rates of UNS S39274, UNS N08535, and UNS N06255 based on mass loss are 0.18 mpy, 0.23 mpy, and 0.09 mpy, respectively. Slow strain rate test results showed no significant loss in ductility, and no secondary cracking when specimens were tested in downhole high chloride conditions. The overall results of the study indicated that these corrosion resistant alloys are able to withstand chloride concentrations beyond the specified limits when H2S partial pressure is low.

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HFW Pipe Seam Screening Test For Susceptibility To Hydrogen Embrittlement

Product Number: MECC23-20105-SG

Author: Saad M. Al-Muaili; Mohammed Al-Anezi; Khalid A. Babakri

Publication Date: 2023

$20.00

HFW pipes is considered a cost-effective pipe option for oil and gas pipeline projects. The HFW seam performance is always a concern, especially in challenging environments such as low temperature applications and wet sour services. One of the challenges include the seam properties to resist sulfide stress cracking (SSC) or hydrogen embrittlement (HE) when exposed to hydrogen charging environment such as a wet sour service.

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Hydrogen Embrittlement Failure Of Nickel Alloy UNS N07716-140 Tubing Retrievable Safety Valve Component Installed In A Sour Production Gas Well

Product Number: 51322-17709-SG

Author: Iyad Al-Buraiki, Qasem Alhassan, Karthik Krishnan, Wade Meaders

Publication Date: 2022

$20.00

A 9-5/8 inch (244.8 mm) Tubing Retrievable Safety Valve (TRSV), which is a type of Sub Surface Safety Valve (SSSV) governed by API Specification 14A, was found to have failed when retrieved during workover operations in a gas production well in June 2019. This TRSV was installed in the well in November 2013 and was in production service from 2015 until November 2018 when the well was shut in for maintenance of surface equipment. In March 2019, with the well still shut in for maintenance, a rapid increase in the tubing-casing annulus (TCA) pressure was observed.

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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.

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Investigating Crack Initiation and Propagation from Hard Spots In TMCP Steels Exposed to Wet Sour Environments

Product Number: MECC23-20109-SG

Author: Maslat Al-Waranbi; Saad M. Al-Muaili; Khalid BaBakri

Publication Date: 2023

$20.00

Hard spot cracking is a type of sulfide stress cracking (SSC), which is a common type of Hydrogen
Embrittlement (HE). The embrittlement by SSC is attributed to the hydrogen atoms (H+), as corrosion byproduct, that permeate/diffuse through the metal with the presence of H2S. Then, when hydrogen atoms get entrapped at specific microstructural configurations, material ductility will be impaired and material will be embrittled [2].

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Investigating The Effect Of H2S And Corrosion Inhibitor On The Corrosion Of Mild Steel Under High Pressure CO2 Conditions

Product Number: 51322-17943-SG

Author: Yoon-Seok Choi, Fernando Farelas, Luciano Paolinelli, Ahmad Zaki B Abas, Azmi Mohammed Nor, Muhammad Firdaus Suhor

Publication Date: 2022

$20.00

Over the past decade, there has been increasing interest in the corrosion behavior of carbon steels in supercritical CO₂ conditions. Unlike the case of carbon capture and storage (CCS) where small amounts of water are present, the exploitation of fields with high pressures of CO₂ needs to consider the presence of formation water, which presents strong corrosivity. It has been reported that the aqueous corrosion rate of carbon steel at high CO₂ pressures (liquid and supercritical CO₂) without protective FeCO₃ corrosion product layers is very high (>20 mm/y) due to the high concentrations of corrosive species such as H⁺ and H₂CO_³.^1-5 Steels with low Cr contents (i.e., 1% Cr and 3% Cr) have shown no beneficial effect in terms of reducing the corrosion rate to admissible values.6 Therefore, controlling corrosion in these cases usually involves the use of corrosion resistant alloys (CRAs) or corrosion inhibitors (CI). Adequate protection of carbon steel was achieved by applying CI in high pressure CO₂ environments.⁶

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Investigation of Sulfide Stress Crack Propagation Using Sour Pipe Burst in Tubulars with Simulated Defects under Pressure

Product Number: 51324-20420-SG

Author: Brian Chambers; Bostjan Bezensek; Sebastian Cravero; Pedro Olivo; Octavio Albores

Publication Date: 2024

$40.00

Seamless oil country tubular goods (OCTG) with defined chemistry and toughness, e.g. API 5CT C110, are utilized as production casing in sour wells globally. These grades must withstand high pressures and mild sour conditions to maintain the integrity of the well and, as such, should resist both sulfide stress crack (SSC) initiation and potential propagation from defects in service. A laboratory study was conducted to assess the tendency of crack propagation from two defined types of defects, electro-discharge machined (EDM) notches and fatigue cracks, simulating potential as-delivered OCTG tubulars. The tubulars were subjected to a variety of test conditions including two temperatures, 4ºC and 24ºC, internal pressures ranging from 550 to 1,100 bar, and exposure to a modified NACE TM0177 Solution B equilibrated with 7% H2S/N2 gas purge. The applied pressure and depth of defects were used to determined applied stress intensity values, K, for each condition to compare tests with one another and to traditional small-scale evaluations per NACE TM0177 Method D, single edge notched tensile (SENT), and constant K compact tension (CT). The findings indicated that tendency towards SSC propagation was principally dependent on type of defect, temperature, and applied K. Threshold K values for SSC propagation from EDM-type defects were higher than determined from any of the small-scale evaluation methods. Fatigue pre-cracks were demonstrated to be more aggressive in promoting SSC propagation compared to EDM-type defects.

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MR0103-2012-Spanish, “Materiales Resistentes a Agrietamiento de Sulfuro por Corrosión bajo Tensión en Entornos de Refinación de Petróleo Corrosivos”

Product Number: 21183-SG

ISBN: 1-57590-168-4

Publication Date: 2012

$179.00

Requisitos materiales para resistencia a tensofisuación por sulfuros (SSC) de soldaduras y microestructuras en ambientes con H2S húmedo ("sour environments").

Products tagged with 'h2s'

Association for Materials Protection and Performance