AMPP Store - Conference Papers

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Field Evaluation of Cathodic Protection Index for Bare and Coated Steel in Seawater

Product Number: 51393-93528-SG

Author: V. Van Blaricum and A. Kumar

Publication Date: 1993

$20.00

Polarization measurements were conducted over a 21-year period on bare and coated steel "H" pilings 6 inch by 6 inch by 30 feet (15.2 cm by 15.2 cm by 9.1 m) installed in seawater. A DC power source was used to shift from the corrosion potential of each pile to -0.85V. The amount of potential shift was recorded as 6V. The current (6I) required to shift the potential was measured, and a nonlinear pseudoresistance (6V/6I), called the Cathodic Protection Index (CPI), was calculated. The CPI was compared with the coating condition of the steel pilings as determined visually using ASTM standards. Results of these tests will be presented and discussed.

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Field Experience Identifying and Investigating Internal Coating Failure in Water Injection Piping

Product Number: 51319-13550-SG

Author: Itoro Akrasi

Publication Date: 2019

$20.00

For a highly corrosive water injection media (wasia water) which has very high total dissolve solid (TDS) and high oxidizing agents internal fusion bonded epoxy (FBE) coatings in addition to corrosion inhibitor was provided for internal corrosion protection of water injection plant Piping.A year after start-up of water injection plant the plant started experiencing internal FBE coating failure. The failed coating were found at the strainer and recycle valve after causing high differential pressure during operation. Seven types of failed coating film were collected from the suction strainer. Comprehensive failure investigation was conducted to determine the root cause of the failure and identify the source of various failed coating films received. Fourier transform infrared spectroscopy (FT-IR) energy dispersive X-ray Spectroscopy (EDS) X-ray diffractometer (XRD) and differential scanning calorimetry (DSC) were all used to identify the type of coating and their manufactures. Robotic video crawler (RVC) was used to inspect the internal coating condition for the piping system. Effect of corrosion inhibitor injection and plant operating parameters on the coatings were all reviewed and evaluated. It was concluded that improper coating application was the root cause of the failure. Keywords: Failure Investigation FBE Coating Robotic video crawler (RVC) Fourier transform infrared spectroscopy (FT-IR) Energy dispersive X-ray Spectroscopy (EDS) X-ray diffractometer (XRD) and Differential scanning calorimetry (DSC).

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Field Experience of Duplex Stainless-Steel Pipes in Stagnant Condition

Product Number: 51324-20361-SG

Author: Amjad Al Kharusi; Janardhan Rao Saithala; Mohammed Al Ghafri; Talal Nabhani

Publication Date: 2024

$40.00

Flowlines in the Oil & Gas industry play a pivotal role in ensuring the safe and dependable production of hydrocarbons. Maintaining their integrity stands as a critical responsibility for all operators. Duplex stainless steel (DSS) materials find extensive use within our organization, particularly in upstream Oil & gas, across various critical applications such as pipelines and flowlines. These DSS pipelines are versatile, serving not only in traditional oil transmission but also in diverse applications like water supply, un-stabilized condensate transportation, and the conveyance of wet gas. In recent years, PDO has faced challenges associated with the premature failure of DSS flowlines and pipelines. These failures have been linked to issues arising during hydrotesting, maintenance, and subsurface fracking operations, primarily due to liquid stagnation. This paper presents a comprehensive case study focusing on premature DSS failures, offering insights into our strategies for preserving the integrity of flowlines during extended well shutdowns.

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Field Experience of Various Coating Systems in Oil & Gas Industry

Product Number: 51324-20360-SG

Author: Amjad Kharusi; Janardhan Rao Saithala; Mohammed Al Ghafri; Mohammed Ossama; Talal Nabhani

Publication Date: 2024

$40.00

Internal and external coatings have been used extensively for the corrosion protection of a wide range of process components such as flowlines, pipelines, piping, vessels, tanks etc. that are used in oil and gas industry. Coatings are a critical barrier as part of a corrosion management strategy and shall be capable of providing long term corrosion protection in corrosive environment. Coatings are exposed to wide range of temperatures, high pressure environments, and acid gases (H2S and CO2), and are subjected to mechanical damage, etc. during operating service life. The authors’ company has extensive experience of using various coating systems for over 40 years. Fusion bonded epoxy (FBE) coatings and glass reinforced epoxy (GRE) linings are primarily used as internal coatings, and three-layer polypropylene (3LPP), three-layer polyethylene (3LPE), thermal spray aluminum (TSA), and epoxy coatings are used as external coatings in hydrocarbon and water injection service. During design, it is anticipated that coatings will meet expected design life, however, premature coating failures are reoccurring for various reasons, which result in significant oil & gas deferment and unplanned shutdowns. This paper will present two case studies on field experience of different coating systems and contributing factors that led to premature failures. The three main contributing factors to premature failure are quality QA/QC during coating application, incorrect coating selection, and coating damage during installation.

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Field Experience On Why Pipeline In-Line Inspections (ILI) Fail

Product Number: 51321-16884-SG

Author: Itoro L. Akrasi; Mohammad S. Hamaqi; Tawfiq I. Hathloul; Abdullah F. Almakinzi; Abdulaziz A. Naim

Publication Date: 2021

$20.00

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Field Metallography and Replication on Liquefied Natural Gas Assets: Non-Destructive Metallurgical Testing to complement other regular Non-Destructive Tests

Product Number: 51320-15140-SG

Author: Anil Kumar Chikkam, Mehrooz Zamanzadeh, Sunil Kumar Pulagam, Ganesh P, Dhandabani, Bangaru Murali, Jeevanandam Shanmugam

Publication Date: 2020

$20.00

During plant shutdown maintenance, some components cannot be removed out of service immediately for metallurgical examination due to high cost involved and loss of production hours. The best alternative is to replicate the lab based metallography work under the field conditions. Field Metallography and Replication (FMR) also known as in-situ metallography is a powerful non-destructive test (NDT) tool used to examine the microstructure of the component when it is still in service. Moreover, FMR is also used to study the microstructural alterations for the fitness for service assessment.

This paper provides case studies of materials in Natural Gas Processing facility where FMR was used as an NDT tool without sectioning the component. This paper discusses the damage mechanisms such as sigma phase embrittlement, stress relaxation cracking and creep.

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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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Individual Conference Papers

Field Evaluation of Cathodic Protection Index for Bare and Coated Steel in Seawater

Field Experience Identifying and Investigating Internal Coating Failure in Water Injection Piping

Field Experience of Duplex Stainless-Steel Pipes in Stagnant Condition

Field Experience of Various Coating Systems in Oil & Gas Industry

Field Experience On Why Pipeline In-Line Inspections (ILI) Fail

Field Metallography and Replication on Liquefied Natural Gas Assets: Non-Destructive Metallurgical Testing to complement other regular Non-Destructive Tests

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

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

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

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

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

Field Trial Findings of a Novel Sulfidogenesis Inhibitory Compound

Association for Materials Protection and Performance