AMPP Store - AMPP Conference Papers

Available for download

A Comparative Study between Corrosion in Sour Environments Generated by Na2S.9H2O Salt and H2S Gas

Product Number: 51324-20762-SG

Author: Hunter Thomson; Scott Fairley; Caroline Simpson; Dario M. Frigo; Gordon Graham

Publication Date: 2024

$40.00

Corrosion tests in laboratories to investigate the corrosion rate and to qualify production chemicals are only valid and applicable if the conditions and chemical environment (pressure, temperature, wall shear, pH, CO2 and H2S partial pressures, electrolyte composition) are representative of the field conditions. Representative sulfide concentrations are sometimes achieved by adding a sulfide salt (e.g., Na2S.9H2O) to minimize health and safety risks associated with the direct use of H2S gas. The current study compares the corrosion of carbon steel in nominally comparable sour conditions generated either using H2S gas or sodium sulfide salt. Tests were performed at 90 °C/101.3 kPa and at 120 °C/20 MPa using H2S partial pressures (pH2S) of 0.1 kPa (0.1 mol% H2S at 1.013 bar), 0.2 kPa (0.2 mol% at 1.013 bar) and 40 kPa (0.2 mol% at 200 bar). The corrosion rate was monitored by linear polarization resistance at ambient pressure and by weight loss measurement at higher pressure. Surface morphology of the coupons was assessed by optical microscopy, scanning electron microscopy (SEM) and energy dispersive X-ray spectroscopy (EDX). Ambient pressure linear polarization resistance (LPR) measurements with low H2S partial pressures showed comparable corrosion rates obtained using either H2S gas or sodium sulfide. In contrast, in the tests at higher pressure, significantly lower corrosion rates were measured when using H2S gas than with sodium sulfide. Moreover, microscopy showed pitting when sulfide was introduced as the salt, but pitting was absent when the sour environment was generated by H2S gas. Supportive work on other systems has shown that small changes in in situ conditions, particularly at elevated pressure (high H2S partial pressure), have a significant impact on the recorded corrosion rates, and therefore the ability to accurately match the environment within the test cell between generating the in situ sulfide via salt addition versus H2S gas is likely to be the root cause. In summary, therefore at high H2S partial pressure, particularly where the corrosion becomes dominated by sour corrosion, such issues related to the test methodology, and the ability to achieve representative in situ conditions, may lead to disqualification of corrosion inhibitor candidates that otherwise could have achieved the pass criteria were testing performed using H2S gas.

Available for download

A Comparative Study on Coating Performance of Inorganic Zinc Primer System and Inorganic Copolymer System by Long-Term Durability Test Including High Temperature Exposure at 540℃

Product Number: 51323-18820-SG

Author: Chuljung Kim

Publication Date: 2023

$20.00

Bulk items such as cast and forged valves are installed under various temperature conditions. It is exposed to a wide range of temperatures, therefore the coating product applied to bulk items should have appropriate heat resistance performance. However, it is very difficult to select a suitable coating system since the temperature condition is not determined in the valve manufacturing stage. For this reason, unsuitable coating systems are often applied, causing coating defects in the field operation. Therefore, it is necessary to apply a coating system that can cover a wide temperature range to prevent this problem.

Available for download

A comparison among different electrochemical hydrogen charging methods tested on low alloy steels

Product Number: 51323-18866-SG

Author: Luca Paterlini, Luca Casanova, Giorgio Re, Marco Ormellese, Fabio Bolzoni

Publication Date: 2023

$20.00

Atomic hydrogen can enter metallic microstructures from deposition processes like Cr plating or phosphatizing, chemical and electrochemical pickling treatments, during welding operations if the humidity of consumables is too high, by cathodic processes resulting from corrosion phenomena or contact with high pressure gaseous hydrogen. According to different chemical-physical mechanisms, atomic hydrogen can enter the metallic structure resulting in damages of various forms, such as HIC (hydrogen induced cracking), SOHIC (stress oriented HIC), delayed fracture and hydrogen embrittlement (HE).

Available for download

A Comprehensive Empirical Evaluation of Probabilistic Corrosion Growth Rate Models

Product Number: 51323-18883-SG

Author: Gabriel Langlois-Rahme, Mahmoud Ibrahim, Miaad Safari, Yanping Li, Chike Okoloekwe

Publication Date: 2023

$20.00

Traditional Corrosion Growth Rate (CGR) models used in the integrity assessment of corroded pipelines are deterministic. A common Magnetic Flux Leakage (MFL) inline inspection (ILI) tool performance specification on general corrosion anomaly depth is +/- 10% Wall Thickeness (WT) at 80% confidence which corresponds to a standard deviation of 7.81% WT. Probabilistic Corrosion Growth Rate (PCGR) models incorporate these large measurement uncertainties and provide more realistic reliability assessments

Available for download

A Damage-Based Approach and Predictive Modeling of Corrosion in Substrate/Coating Systems Using Artificial Neural Networks

Product Number: 51324-21150-SG

Author: Victor Ponce; Walter Tarr; Allison Mahood; Heather Eich; Homero Castaneda

Publication Date: 2024

$40.00

The long-term performance of three different automotive surface coatings (physical barrier, sacrificial, and hybrid) was predicted using electrochemical impedance spectroscopy (EIS). Corrosive conditions faced by vehicles in the field, such as deicing, can be simulated using accelerated methods. The coating/metallic substrate interface experiences various degradation mechanisms during exposure to harsh conditions. In this work, real-time measurements were performed via EIS testing to characterize the degradation and corrosion mechanism of coating and substrate. After the real-time measurements, a mathematical framework based on mechanistic and machine-learning concepts was developed. Phase angle plots from EIS were utilized to monitor the state of the coating during steady-state conditions and train the Artificial Neural Network (ANN) as an arrangement of Time Series Prediction (TSP). The transport processes, activation, and interface interaction with the corrosive environments were analyzed as a corrosion mechanism and were predicted via the ANN model. The ANN has predicted the coating performance for several years, and the experimental results have been validated by employing scanning electron microscopy (SEM) imaging. Each coating condition has been validated via SEM imaging at the initial state and when the coating protection is activated.

Available for download

A Data Driven Approach to Improving Suitability of External Corrosion Risk Algorithm for Pipelines with Unique Operating Conditions – A Case Study of Hot Bitumen Pipelines

Product Number: 51323-19170-SG

Author: Cathy Lee Tetreault, Qing Lan

Publication Date: 2023

$20.00

Suncor is an integrated oil, gas exploration, and production company that operates over 1000 km (622 miles) of pipeline in Canada and approximately 386 miles (621 km) of pipeline in US. Suncor also operates refineries in Alberta, Ontario, Quebec (Canada) and in Colorado (USA). Additionally, the company owns a network of more than 1,800 Petro-CanadaTM retail and wholesale locations across Canada.

Available for download

A Data-Driven Approach to Predicting Oxidation Rate Constants For Alloys

Product Number: 51323-19412-SG

Author: Christopher D Taylor

Publication Date: 2023

$20.00

High-temperature service places severe constraints on materials selection due to a combination of factors including the formation of oxide films, spallation and volatilization, and deterioration in mechanical properties. Materials selection is principally informed by laboratory testing under simulated conditions of temperature, thermo-mechanical fatigue, and environment chemistry (such as the presence of steam, exhaust gas chemistry, or salts). Models for predicting the high temperature performance of materials a priori are an active area for development, and are currently focused on elements such as predicting oxide formation, microstructure evolution and reduced order models for creep.

Available for download

A decision support tool for best coating selection during trenchless pipe installation

Product Number: 51323-18849-SG

Author: Thierry Kerzerho, Pascal Aussant, Eric Parizot, Ahmed Fakhry, Alexandre Royer

Publication Date: 2023

$20.00

In the recent years, Horizontal Directional Drilling - HDD - became a real improvement for pipeline construction when crossing obstacles such as rivers, roads or railways. For the corrosion protection of the carbon steel pipeline, a protective coating is associated with cathodic protection. But for trenchless techniques, the coating shall withstand the stresses from the installation. Several standards are used to specify corrosion protection coatings for buried pipelines but those documents do not cover the specific conditions of an HDD.

Available for download

A Disposable Electrochemical Biofilm/MIC Test Kit to Detect MIC and to Assess Efficacy of Biocide Treatment of Biofilm

Product Number: 51324-20887-SG

Author: Lingjun Xu; Adnan Khan; Sith Kumseranee; Suchada Punpruk; Pruch Kijkla

Publication Date: 2024

$40.00

Microbial biofilms are behind microbiologically influenced corrosion (MIC). Currently, all the so-called MIC test kits on the market are actually microbe test kits. Our new disposable miniature electrochemical biofilm/MIC test kit based on 10 ml serum vials with solid-state electrodes fills the gap to provide corrosion information such as abiotic corrosion vs. MIC, and MIC by electron-harvesting biofilms vs. MIC by corrosive metabolites. It can also test antimicrobial efficacy. An electrochemical workstation is used as a base station to perform various electrochemical scans such as linear polarization resistance, electrochemical impedance spectrometry and potentiodynamic polarization scans to provide near-real time transient corrosion data after a fluid or sludge is injected into the vial. This work presented a prototype with two different solid-state electrode choices. Three different methods to distinguish MIC from abiotic corrosion, and two different methods to distinguish MIC by electron-harvesting biofilms from MIC by corrosive metabolites. Anaerobic Desulfovibrio ferrophilus IS5 (a highly corrosive sulfate reducing bacterium) biofilm, aerobic Pseudomonas aeruginosa biofilm and an anaerobic corrosive oilfield biofilm consortium were used as examples. Tetrakis hydroxymethyl phosphonium sulfate (THPS) biocide was used as an example for assessing biocide efficacy. The patent-pending technology is currently undergoing field-testing.

Available for download

A Fracture Mechanics Approach To Characterizing Hydrogen Embrittlement Of Fasteners

Product Number: 51321-16798-SG

Author: Herman E. Amaya, Behrang Fahimi, Ramgopal Thodla

Publication Date: 2021

$20.00

Materials properties that are used in specific oil and gas environments are de-rated due to the risks associated with hydrogen embrittlement cracking. In oil production environments the concern is for the onset of stress corrosion cracking (SCC), while in seawater environments the concern is for Hydrogen Induced Stress Cracking (HISC). Both are hydrogen embrittlement phenomena with the distinction being the source of hydrogen for each. In SSC the source of hydrogen is from the presence of H2S in the oil production fluids, and in HISC the source of hydrogen is from the dissociation of water from the cathodic protection system. This paper is focused on the latter phenomena and aims to characterize the susceptibility of carbon alloy steels as applied in fastener applications, in a seawater environment under cathodic protection.

Available for download

A Further Look At The Impacts Of Corrosion Inhibitor On Scale Prevention

Product Number: 51322-17676-SG

Author: Qiwei Wang, Tao Chen, Hameed Al-Badairy, Sultan Alsubaie, Yasser Al-Jeshi, Mohammad Alsidan

Publication Date: 2022

$20.00

Scale and corrosion inhibitors are commonly used in many oil and gas production systems to prevent inorganic deposition and to protect asset integrity. Scale inhibitor products are based on organic compounds with phosphate or carboxylic functional groups such as amino phosphonates, phosphate esters, phosphino polymers, polycarboxylate and polysulfonates,1 as shown in Figure 1. These anionic groups have strong affinity to alkaline earth cations and can adsorb on the active growth sites of scale crystal (Figure 2), resulting in stopping or delaying the scale formation process.

Available for download

A High Performance Solvent Free Epoxy Coating Which is Applicable for High Temperature Immersion Environment

Product Number: MECC23-20000-SG

Author: Seunghyun Yang; Gokgeun Kim

Publication Date: 2023

$20.00

Crude oil and its derivate have many applications in almost all industries as O&G are the main resources that move the entire world. The oil and gas industry operate in demanding environments that pose significant challenges to equipment and infrastructure integrity. Facilities such as Gas Oil Separation Plant (GOSP) tanks, submerged areas, DGA columns, desulfurization units, and sour gas treatment facilities are subjected to high temperatures, corrosive substances, and harsh operating conditions.

AMPP Conference Papers

Association for Materials Protection and Performance