AMPP Store - Online Conference Paper

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Guidelines For The Collection Of Reliable And Practicable ECDA Indirect Inspection Data

Product Number: 51322-17978-SG

Author: Miqdaad Fatakdawala

Publication Date: 2022

$20.00

The External Corrosion Direct Assessment (ECDA) is formally listed as an acceptable integrity assessment method within Subpart O, Part 192 of the code of federal regulations regarding gas transmission pipeline integrity management2. It is a 4 step continuous improvement process to identify and address locations where external corrosion activity has occurred, is occurring or may occur1. In the pre-assessment phase, a comprehensive right-of-way inspection is performed, and pipeline operability data is collected to verify the feasibility of conducting a full ECDA for the pipeline under evaluation. In the indirect inspection phase, the status of cathodic protection and pipeline coating is tested using methods such as Close Interval Potential Surveys (CIPS) and Direct Current Voltage Gradient (DCVG) surveys.

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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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Gypsum Scale Inhibitors Performance in the Presence of Impurities

Product Number: 51321-16707-SG

Author: Zahid Amjad

Publication Date: 2021

$20.00

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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.

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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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Handling Extreme Environments With Supoxy Platform Technology

Product Number: 51322-17643-SG

Author: Justin Manuel

Publication Date: 2022

$20.00

One can find some of the most aggressive and corrosive environments for coatings in the process work and equipment functions for Oil and Gas Upstream facilities. These conditions have typically been handled using traditional coating options such as vinyl esters, epoxies, or baked phenolic linings. While these products are often tailored to environments with elevated temperatures and pressures found within upstream and “downhole” oil and gas production, the inception of new drilling techniques and the discovery of new shale basins has morphed the landscape of corrosive environments in this market.

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Hardness And Nickel-Based Alloys

Product Number: 51323-18806-SG

Author: Robert Badrak, Julia Botinha, John Groth, Helena Alves

Publication Date: 2023

$20.00

This paper addresses the relationship between hardness and environmental cracking resistance in nickel base alloys. The work here builds on the presentation made to AMPP’s SC08 Fall 2021 meeting on October 19th.

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Heat buildup for Thermally Insulative Coatings due to Solar Exposure: Efforts in Modeling and Prediction

Product Number: 51323-19496-SG

Author: Nathan R. McCormick, Victoria J. Gelling

Publication Date: 2023

$20.00

Human safety is at the forefront of industrial concerns, with manufacturers needing to comply with multiple standards globally and regionally. One such concern is ensuring that those working in close contact with surfaces of elevated temperature are protected against injury and burns. You will find that many will reference the fact that the U.S. Occupational Safety and Health Administration (OSHA) has set a limit of safe temperature for skin contact at 140°F (60°C) and state that these limits were set since no damage would occur during five seconds of exposure.

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Heat Treatment of Heat Exchanger U-bends - Practices on Different Materials and Case Histories of Failures

Product Number: 51324-20815-SG

Author: Shahab Soltaninia; Zesan Ardaniel; Cathleen Shargay; Sarah Radovcich

Publication Date: 2024

$40.00

There is currently confusion and differing practices being specified by purchasers, Shell-and-Tube Heat Exchanger (S&T HX) fabricators and/or U-bend suppliers regarding when and how to heat treat tubing U-bends. The need for Heat Treatment (HT) varies based on the material, service, and tightness of the bend (i.e., the degree of strain). The methods used for heat treating are typically furnace or Electric-Resistance (ER). This paper first summarizes the international codes and standards requirements for S&T HX U-bend heat treatment. Next it provides the highlight of some industry studies and compiles case histories of U-bend failures from literature and conference minutes. The overall goal for this paper is to propose possible initial changes to the relevant standards with future changes being added after the additional testing.

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Hexacyanoferrate-Intercalated Layered Double Hydroxides As Nano-Additives For Detection Of Early-Stage Corrosion Of Steel

Product Number: 51321-16740-SG

Author: M. Wilhelm; M. Reyes; A. Sushkova; J. Yang; B. Wabende; M. Pilz; R. Martins; S. Loureiro; C. Simon; J. Tedim

Publication Date: 2021

$20.00

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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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Hibernation of Ducts with CRA Alloys: Standardization of Methods for the Chemical and Microbiological Composition of Operation Seawater

Product Number: 51324-20678-SG

Author: Walter Cravo; Flávia Maciel Fernandes Guedes; Maíra Paula de Sousa; Vinicius de Abreu Waldow; Luiz André Lucas Teixeira Pinto

Publication Date: 2024

$40.00

The work aimed to standardize the initial chemical and microbiological composition of seawater used in hibernation studies, due to the seasonality to which these waters are subject throughout the year. Bioaugmentation vs. biostimulation techniques were tested to increase microbial growth and test seawater with greater biocorrosive potential, obtaining more conservative results. Different seawater samples off the coast of Rio de Janeiro/Brazil were tested to validate the experimental model. Cultivation and molecular biology techniques were used for microbial monitoring. At the same time, the concentration of dissolved oxygen in the standardized fluid was monitored. The biostimulation technique was the most appropriate, maintaining a high bacterial concentration throughout the experiment. Population analysis by metagenomics revealed the presence of bacterial groups that promote biocorrosion in all waters and a change in the population profile over time, revealing the adaptability of certain groups. The oxygen concentration decreased over time reaching ppb levels.

Online Conference Paper

Association for Materials Protection and Performance