AMPP Store - Individual Conference Papers

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Grooving Corrosion of Electric Resistance Welded Steel Pipe In Water: Case Histories and Effects of Alloying Elements

Product Number: 81075-75-SG

Author: Katsumi Masamura, Iwao Matsushima

Publication Date: 1981

$20.00

In view of the increased frequency of grooving corrosion in electric resistance welded(ERW)steel pipes used for water pipes, case histories and factors affecting its occurrence have been investigated. Two types of grooving corrosion are observed in 68 case studies of troubled pipes, the continuous and discontinuous types. The latter is associated with tuberculation, deep penetration being limited to the weld area covered by tubercles. The penetration rate is 2.Smm/y (lOOmpy) in average and 9.5mm/y (380mpy) at maximum, corresponding to 25 and 80 times, respectively, that of the overall corrosion rate in water.
There is a general tendency that a high penetration rate is associated with wates of low specific resistance. This type of corrosion occurs not only on the water side but also on the outer surfaces that are in contact with soil or insulating materials soaked with water . The chemistry and manufacture do not seem to affect the susceptibility as far as the commercial products are concerned Since the differences in chemistry and microstructure between the weld and the base metal exist practically in all commercial ERW pipes, there is a potential danger of grooving corrosion.

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GS-11/GS-3 Paints Revision

Product Number: 41208-414-SG

Author: Chris Fisher

Publication Date: 2008

$20.00

Green Seal is modifying its coating standard, GS-11, to reflect today’s environmental concerns. The biggest area of concern is greenhouse gases, global warming, energy conservation and Urban Heat Islands which is referenced under the Kyoto Treaty, EPA Clean Air Act, California AB 32, Title 24 and other air quality legislation. Green Seal can address these concerns by including a new energy-efficient requirement in to its new coating standards.

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Guidance for Materials Selection and Corrosion Control in CO2 Transport and Injection for Carbon Capture and Storage

Product Number: 51322-17726-SG

Author: J. Sonke, S.J. Paterson

Publication Date: 2022

$20.00

The aim of this work is to identify an approach to materials selection and corrosion control that can address the specific requirements of a Carbon Capture and Storage (CCS) project. This work is largely based on the accumulated knowledge and expertise that has been published. Besides the direct guidance from this document, specific topics may require more detail that can be found in the references.

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Guidance For Thermal Stability Of Common Oilfield Chemicals

Product Number: 51322-17745-SG

Author: Tracey Jackson, Johnathon Brooks, Zhengwei Liu, Sunder Ramachandran

Publication Date: 2022

$20.00

As oilfield technologies have advanced, they have made high temperature (HT) reservoirs more accessible. HTs make the application of chemical more difficult because chemical instability at HT restricts what intermediates will work in these environments and the safety and complexity of HT testing further adds to the challenge.

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Guideline To Determine Erosional Velocity For Liquid Hydrocarbon Transmission Pipelines

Product Number: 51322-17812-SG

Author: Jose Vera, Francois Ayello, Guanlan Liu, Richard Eckert, Prabhas Bhat

Publication Date: 2022

$20.00

Erosion is a major threat to liquid hydrocarbon transmission pipeline integrity when high liquid flow ratesare combined with the presence of solid particles. However, there is currently no generally acceptedguidance document or standard by which liquid petroleum pipeline operators can define maximum allowable velocities to manage the threat of erosion in their pipelines.

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Guidelines for Corrosion Inhibitor Selection for Oil and Gas Production

Product Number: 51317--8842-SG

ISBN: 8842 2017 CP

Author: Johannes Sonke

Publication Date: 2017

$20.00

Recommended corrosion inhibitor (CI) testing methods and interpretation to assure proper execution of a test program. Associated guidance for CI test program definition testing and management to ensure and improve the integrity of carbon steels applications in our Industry.

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Guidelines for Proper Care and Restoration of EIFs and Non-EIFs Exteriors

Product Number: 41211-600-SG

Author: Robert W. Dazel

Publication Date: 2011

$20.00

The primary scope of this paper is to outline guidelines for cleaning, repairing, and restoring / renovating Exterior Insulation and Finish Systems (EIFS) and non-EIFS exteriors.

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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

Available for download

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.

Individual Conference Papers

Association for Materials Protection and Performance