AMPP Store - Products tagged with 'sour corrosion'

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Assessment Of Precorrosion Methods For Inhibitor Testing Under Sour Conditions

Product Number: 51322-17903-SG

Author: Attila Palencsár, Rolf Nyborg

Publication Date: 2022

$20.00

Development of new oil and gas fields is likely to involve sour reserves to an increasing degree. Sour
production often brings about difficulties in terms of asset integrity, related particularly to corrosion
mitigation. Employing corrosion resistant alloys implies a considerable escalation in investment costs. On this basis the use of carbon steel and CO2/H2S corrosion inhibition remains a highly desirable
option.

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Downhole Sour Corrosion And Scale Deposition In Oil Wells

Product Number: 51322-17694-SG

Author: Tao Chen, Frank Chang, Feng Liang, Steven Hochanadel

Publication Date: 2022

$20.00

Sour corrosion and iron sulphide scale deposition are two common flow assurance issues encountered in oilfields. Sour oil wells typically produce crude along with produced water and a significant amount of acidic gases such as carbon dioxide and hydrogen sulfide. The high pressure and temperature conditions under the downhole tend to cause severe corrosion damage including metal loss and pitting, along with iron sulphide scale deposition. Iron sulfide deposition in sour wells is a corrosion induced scale problem. It potentially causes production decline, restricted well intervention, well shutdown, or even severe consequences towards to the abandoned wells.

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Effect of Acetic Acid on Sour Corrosion of Carbon Steel

Product Number: 51317--9318-SG

ISBN: 9318 2017 CP

Author: Jon Kvarekval

Publication Date: 2017

$20.00

An experimental study of corrosion of carbon steel in the presence of H2S, CO2 and acetic acid has been carried out. H2S and CO2 partial pressures up to 10 bar each were applied, with temperatures of 25 and 90oC.

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Effect of H2S Concentration on the Passivation Behavior of Modified 13 Cr Martensitic Stainless Steels

Product Number: 51324-21009-SG

Author: Alan Martinez; Deeparekha Narayanan; Raymundo Case; Homero Castaneda; Ahmed Baghat

Publication Date: 2024

$40.00

Modified 13 Cr Martensitic Stainless steels (UNS S41426) are used extensively in the oil and gas industry as wellbore components in sweet and moderately sour service applications. The synergistic effects between H2S activity and temperature have a detrimental effect on the passive film stability. Electrochemical tests were performed using a 1L autoclave holding 35 bar of CO2 gas and varying H2S activity at 25°C and 150°C at a pH of 3.5. The pitting susceptibility is enhanced in regions along Ti(C,N) inclusions and regions where defective sulfide films generate local galvanic cells around regions with limited protection along the steel surface further driving the pitting process. Both DC and AC electrochemical techniques were correlated with microstructural characterization to observe the extent of passivation on the surface. Some service limits under acidic conditions are proposed based on the electrochemical results.

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Effect of H2S on the Corrosion and Cracking Behavior of Welded API 5L X65 Steel in Supercritical CO2

Product Number: 51321-16407-SG

Author: Shiladitya Paul

Publication Date: 2021

$20.00

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Effect Of H2S On The Performance Of Welded 13% Cr Steel In Supercritical CO2

Product Number: 51322-17886-SG

Author: Shiladitya Paul

Publication Date: 2022

$20.00

Carbon steels such as API 5L X65 are widely used oil and gas exploration, production and transportation service. However, these steels tend to corrode in the presence of wet CO2 and corrosion is more pronounced in the presence of dissolved salts and acids. Other metals, alloys and polymers also degrade in the presence of high pressure gaseous and supercritical CO2. The corrosion rate of carbon steels in some aqueous environments have been reported to be more than a few millimeters per year.9-10 The situation could be further exacerbated by H2S where cracking can be an issue for high strength steels.

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Effect of Temperature on Iron Sulfide Formation and Transformation on Steel Surface

Product Number: MECC23-19971-SG

Author: Abdulrahman Alqahtani; Faisal Abbas; Omar Al-Saif; Layan AlSharif; Muthukumar Nagu; Christian Canto Maya

Publication Date: 2023

$20.00

In sour (H2S) corrosion systems, a small amount of H2S can retard the general CO2 corrosion rate of carbon steel by forming a passive iron sulfide (FeS) layer [1], [2]. Environmental factors dictate the formation of protective or partially protective FeS layers on carbon steel surfaces. High H2S levels often result in stable films that reduce the corrosion rate, contingent upon the maintenance of the sulfide layer [2]. Conversely, in slightly sour systems, which initially form mackinawite (FeS) [3], the system has the potential to cause pitting and extremely high localized corrosion rates [2].

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Evaluation of a Hydrophobic Coating Material for Downhole Application, Lab vs. Field Evaluation

Product Number: 51324-20756-SG

Author: Tao Chen; Feng Liang; Frank Chang; Qiwei Wang

Publication Date: 2024

$40.00

A hydrophobic electroless nickel-phosphorus (ENP) coating material has been developed to reduce corrosion-induced iron sulfide scale deposition. The ENP coating has several key advantages to provide corrosion resistance for sour oil and gas applications, including a level of phosphorus imparting superior corrosion resistance in a sour gas environment, a tailored phosphorus level providing a range of super hydrophobic microstructures, and a second material introduced and embedded in the ENP coating during the coating process to impart desired properties such as wear and erosion resistance. The coating material has been qualified through a series of evaluation tests carried out in the lab, including iron sulfide scale formation under HTHP, coating adhesion tests, explosive decomposition, formation of heazlewoodite (Ni3S2), etc. The coating material was installed in downhole completion tubing through a downhole corrosion and scale monitoring (DCSM) tool to monitor coating stability, corrosion, and scaling under real downhole flow conditions in a sour gas well over 3 months. Overall, the field testing has demonstrated that this newly developed coating material can effectively protect the metal coupon against corrosion and iron sulfide deposition. However, the abrasion of the formed surface layer of Ni3S2 and blistering might be a concern for a long-term field application. This paper will comprehensively compare the coating performance evaluated in the lab and field conditions. Long-term evaluation under real field conditions is highly recommended to qualify the coating material for large-scale application in the downhole.

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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.

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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.

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Investigation on Localized Corrosion Resistance of Nickel-based alloy UNS N07718 under Sour conditions of PuGuang Field simulated Environment

Product Number: 51322-17761-SG

Author: Erfan Abedi Esfahani, Frederick Pessu, Jiong Qian, Anne Neville, Richard Barker

Publication Date: 2022

$20.00

Extremely corrosive environments of today’s oil and gas exploration requires more expensive Corrosion Resistant Alloys (CRAs) to be used for equipment such as tubulars. Material selection for oil and gas wells, especially those containing high hydrogen sulfide (H₂S) and carbon dioxide (CO2) partial pressure, is very crucial. Hydrogen sulfide and carbon dioxide are quite aggressive to the materials used in oil field environments. The material of choice for these oil wells has to be reliable and cost-effective. This makes the material selection process a very complex and difficult task involving both financial and safety risks analysis.

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Iron Source in Sour Gas/Condensate Wells: Reservoir Fluids or Corrosion?

Product Number: 51317--8998-SG

ISBN: 8998 2017 CP

Author: Giulia Verri

Publication Date: 2017

$20.00

In order to implement an effective iron scale mitigation strategy, operators first need to identify the main source of iron in the system. This work describes a method to predict the “maximum dissolved iron” (MDI) concentration in a reservoir/production system.

Products tagged with 'sour corrosion'

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