AMPP Store - Individual Conference Papers

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Field Study of Corrosion Inhibition Effect on Corrosion of Low Flow Velocity Gas Flowlinesunder CO2 Environments

Product Number: MECC23-20102-SG

Author: Muhammad Sohaib Khan; Mohammed S. Alqahtani

Publication Date: 2023

$20.00

Carbon Dioxide (CO2) corrosion of carbon steel (sweet gas corrosion) poses a serious problem in oil and gas production, since most used materials are low alloyed carbon steels, which are not corrosion resistant. Basically, the main aspects of CO2 corrosion are well known today, and the parameters are temperature, CO2 partial pressure, pH value, and flow velocity [1-2]. CO2 dissolves in brine to form an acidic solution that corrodes carbon steel equipment.

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Field Test and Regularity Analysis of Metro Dynamic DC Stray Current on Buried Gas Pipeline

Product Number: 51323-19146-SG

Author: Shuaijie Ma, Yanxia Du

Publication Date: 2023

$20.00

In recent years, with the large-scale construction of natural gas and metro systems, a lot of buried gas pipeline close to the metro systems have suffered from dynamic DC stray current interference. This may cause corrosion leakage of buried gas steel pipeline and bring serious safety hazards. A large number of corrosion cases from metro stray current have been reported all over the world.

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Field Testing – The Correlation Between Accelerated Laboratory Tests and Field Testing

Product Number: 51319-13154-SG

Author: Anders W. B. Skilbred

Publication Date: 2019

$20.00

All protective coatings are thoroughly tested using accelerated laboratory tests. Accelerated testing has the advantage of providing data and results in a relatively short timeframe and the conditions of testing are pre-defined and controlled throughout the test. However accelerated testing also has disadvantages. Accelerated testing at e.g. tougher environmental conditions or higher temperatures may give different degradation mechanisms than at in service conditions.Field exposures can be used as a supplement to accelerated testing and can be utilized as a verification of the test setup.In this paper results from several atmospheric accelerated laboratory exposure tests for numerous protective coating systems have been compared to results obtained from up to nine years of field exposure testing in a marine environment corresponding to corrosion category C5 according to ISO 12944-2.The comparison shows varying correlation between accelerated laboratory tests and field exposures. This indicates that high performance of a coating system during accelerated laboratory testing is not necessarily predictive for high long term performance under in-service conditions. Potentially causing premature coating failures under in service conditions.The authors therefore propose ailormade test scheme for the various generic coatings and the in-service conditions and for the industry to accept a more holistic view on coating performance.

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Field Testing of Self-Healing Metallic Coatings for Internal Corrosion Protection of Natural Gas Pipelines

Product Number: 51323-18857-SG

Author: Zineb Belarbi, Ömer N. Doğan, Patrick Carr, Richard E. Chinn, Julius Samson

Publication Date: 2023

$20.00

Natural gas pipelines are subject to internal corrosion. Internal corrosion of steel pipelines can cause natural gas leakage, leading to wasted energy, explosion hazards, and methane emissions. The U.S. Department of Transport reported numerous case histories of corrosion problems and failures in wet gas pipelines. The National Energy Technology Laboratory (NETL) performed an incident survey from 2010 through 2018 and found that 112 (12%) of these incidents in the U.S. transmission lines were caused by internal corrosion.

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Field Testing of Well Completion Materials in the Gulf of Thailand (GOT) Conditions

Product Number: 51319-12748-SG

Author: Silakorn Passaworn

Publication Date: 2019

$20.00

PTTEP field experience in GOT and literature search suggested that the carbon steel tubing could replace 13% Cr stainless steel for well completion to some certain depth. The project Well Completion Material Optimization had therefore been applied in-house field test tools since October 2015 to verify this hypothesis.150 test coupons were installed in 7 representative wells which were selected based on production parameters contributing to metal-loss corrosion mainly due to CO2. Since temperature was assumed to have the most impact on general corrosion (metal loss) the installation positions of the test coupons were selected to simulate various temperatures by varying depths.Assessment on the field-tested coupons indicated that the coupons installed at the surface positions and some coupons installed at downhole positions were exposed to flow-assisted corrosion-erosion heavily resulting from flow velocity and turbulence. These were excluded from corrosion assessment.All the rest of the coupons could be used to assess corrosion due to CO2. Corrosion rates had been assessed to be 0.0688 mm/yr. Major corrosion protection mechanisms had been confirmed to be the formation of FeCO3 protective films. Positive results from such field testing indicated that well completion materials could be carbon steel up to some certain level.Key Words: Well Completion Material Material Testing CO2 Corrosion Corrosion Assessment

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Field Trial Findings of a Novel Sulfidogenesis Inhibitory Compound

Product Number: 51319-13168-SG

Author: Alicia Jones

Publication Date: 2019

$20.00

Due to its contribution to microbiologically influenced corrosion and potential HS&E consequences hydrogen sulfide (H2S) presents many challenges to oil and gas production operations. Microbiologically generated H2S is often more difficult to address because it is not present at the onset of production but becomes a problem over the course of the lifetime of a well/asset. Many different types of microbes are responsible for H2S production and reservoir souring. These microbes are capable of reducing not only sulfate but most available sulfur compounds that are present in the reservoir. A new class of compounds was recently identified and characterized in the lab as effective inhibitors or microbial sulfidogenesis. In this work we present results from a field trial conducted using one of these chemistries. The trial showed that this novel inhibitor retained activity under downhole conditions and resulted in significant reductions in the H2S produced within the reservoir as well as the levels found at the central gathering facility. These findings further support the potential of these compounds as solutions to reservoir souring and highlight the need for additional field applications.

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Field-Testing Procedures on a Metallic Pipeline Collocated with an HVDC Powerline

Product Number: 51323-19035-SG

Author: Andrew Mackey, Alex Ristow

Publication Date: 2023

$20.00

Development of this strategy began after a steel pipeline, coated with Fusion Bonded Epoxy (FBE), was constructed in a collocated right-of-way (ROW) with a high voltage direct current (HVDC) Powerline. Area Cathodic Protection (CP) Technicians reported challenges in recording stable DC Pipe-to-Soil (P/S) Potentials due to rapid fluctuations observed in the DC waveform. In addition, CP technicians recorded DC line current concurrently with P/S potentials and found that there was a correlation between the two.

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Fifteen Years History of Cathodic Protection of a Bank in Jeddah Saudi Arabia

Product Number: 51314-3623-SG

ISBN: 3623 2014 CP

Author: John Nicholson

Publication Date: 2014

$0.00

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Finding the Smoking Gun: Lessons Learned from an HDD Coatings Challenge (Coatings Applications Aren’t as Simple as They Appear)

Product Number: 51323-19008-SG

Author: Karen Bowman, Valerie Sherbondy, Lake Barrett

Publication Date: 2023

$20.00

Longitudinal cracking had occurred in the protective ARO pipeline coating scheduled for installation. Once the cracks were discovered the cause and extent of the cracking needed to be identified before work could continue. Industry experience has shown that coating failures do not always have a singular cause and often are the result of multiple interacting variables. In addition, the interaction of these variables can be complex in nature.

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Findings from a Three-year AC Corrosion Field Study

Product Number: 51319-12907-SG

Author: Sorin Segall

Publication Date: 2019

$20.00

A field study was conducted to determine the influence of the AC current density and of the coating holiday size on the rate of AC corrosion.This field study involved burying steel coupons of three different sizes (i.e. 1 cm2 6 cm2 and 10 cm2) applying cathodic protection to an industry standard and varying AC current densities (i.e. 20 A/m2 50 A/m2 and 100 A/m2) for a three-year period. Four sets of twelve coupons each were installed for statistical relevance. Each set contained three coupons with no AC current applied (i.e. placebos) one for each size. A special power supply cabinet was designed to provide uninterrupted DC and AC current with each coupon being energized by a separate module.At the end of the test scheduled for July 2018 the coupons will be retrieved cleaned photographed and the corrosion rate measured.This paper covers the results of the study as well as the various findings from three years of data collection including the effect of AC currents on the protection level of the coupons in clayish soils accuracy of recording DC potentials under AC interference changes in the spread impedance due to calcareous deposits and effects of very high AC voltages on the calcareous deposits.Keywords: AC corrosion AC current density holiday size DC current density polarized OFF potential AC coupons AC/DC power supply cabinet.

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Finish Standards For Intumescent Cellulosic Fire Protection

Product Number: 51322-18100-SG

Author: Max Tritremmel

Publication Date: 2022

$20.00

When choosing a Fire-Protection material to meet building code requirements to insulate steel for a prescribed period to facilitate safe evacuations and emergency response from commercial buildings in the event of a fire, there are many factors that influence the selection of an Intumescent Fire Resistive Material (IFRM) over a Spray Applied Fire Resistive Material (SFRM). It could be a concern of the weight of the system; Portland Cement based SFRM’s are typically much heavier and bulkier than IFRM’s. Another factor could be durability, based on either corrosion resistance or the ability to withstand considerable physical or environmental damage.

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Finite Element Analysis to Locate Maximum Values of the First and Second Principal Strains in the Tensile Pull-Off Test for Coating Adhesion on Large Pipes

Product Number: 41214-814-SG

Author: S. G. Croll, C. Siripirom, B. D. Keil

Publication Date: 2014

$20.00

The tensile pull-off test, as in ASTM 4541, in which a round metal ‘dolly’ is glued to a coating then pulled off is a very common method for measuring adhesion of a coating to its substrate. This technique is very well known to produce joint failures that are not at the intended coating steel interface but may initiate within the coating, within the glue or at the glue-coating interface.

Individual Conference Papers

Association for Materials Protection and Performance