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Picture for Development of a Prediction Model for High pCO2 Corrosion of Mild Steel
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Development of a Prediction Model for High pCO2 Corrosion of Mild Steel

Product Number: 51319-13157-SG
Author: Yoon-Seok Choi
Publication Date: 2019
$20.00

Most of the corrosion prediction models used for design of oil and gas lines carrying high pCO2 are valid up to 10-20 bars of pCO2 and are very conservative at higher pCO2 because they do not account for the effect of high pCO2 on the water chemistry and the corrosion mechanism. The present work was focused on developing a predictive tool for near-critical and supercritical CO2 corrosion of mild steel. It incorporates changes in the water chemistry module due to update solubility and dissociation equations changes in the electrochemical module due to the presence of a thick and porous corrosion product layer and consideration of an adsorption mechanism for H2CO3 at the steel surface. The comparison between experimental results and model predictions showed a good agreement under various pressure and temperature ranges.
Picture for Development of a Probabilistic Model for Assessing Pipeline Third Party Damage Threats
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Development of a Probabilistic Model for Assessing Pipeline Third Party Damage Threats

Product Number: 51319-12719-SG
Author: Shan Guan
Publication Date: 2019
$20.00

Third Party Damage (TPD) represents the largest threat to the integrity of onshore oil and gas pipelines. There exist needs for developing reliable models that can quantify the probability of pipeline exposure to TPD threats. Bayesian network(BN) modeling possesses the advantage to quantify the uncertainties and identify where the reduction of these uncertainties has the greatest benefit in terms of the overall failure. This paper reports a modeling approach using Bayesian Network to quantify the Mechanical damage (a major form of TPD) threats to pipeline. Case studies to exam excavation and moving vehicles damages to the pipeline were reported where the conditional probability tables (CPT) of the model were created based on the pipeline operator’s records public data-bases and literatures as well as information obtained from Subject Matter Experts. This model examines TPD failure mechanisms in three parts including Exposure (likelihood of a force or failure mechanism reaching the pipe when no mitigation applied) Mitigation (actions devices conditions etc. that keep the force or failure mechanism off the pipe) and Resistance (the system’s ability to resist a force or failure mechanism applied to the pipe). Using this model pipeline segment with a higher risk to excavation and moving vehicles damages can be identified and suitable mitigation technology can then be implemented to reduce the risk.
Picture for Development of a Reproducible Ultrasonic Thickness Monitoring Program for Gas Storage Facilities
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Development of a Reproducible Ultrasonic Thickness Monitoring Program for Gas Storage Facilities

Product Number: 51319-12918-SG
Author: Paul Young
Publication Date: 2019
$20.00

Regulatory groups require gas storage facility operators to address the safety and environmental concerns that would be impacted due to a release of the processing fluid. The objective of this paper is to disseminate a process that operators can use to develop an ultrasonic thickness (UT) monitoring program with reliable and reproducible results that meet the fitness-for-service requirements set forth by industry. This paper targets Class 1 Type A components using a Level 1 assessment approach. These components represent the high risk assets subject to design equations that specifically relates to pressure and where supplemental loading does not govern required wall thickness i.e. the required thickness is based on pressure only. A systematic approach to the organization and implementation of the program complete with mathematical equations to evaluate components for fitness-for-service requirements and justification for asset retirement is provided.
Development of a Slurry Erosion Test standard of Industrial Maintenance Coatings
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Development of a Slurry Erosion Test standard of Industrial Maintenance Coatings

Product Number: 41215-936-SG
Author: David Tordonato, Bobbi Jo Merten, Allen Skaja
Publication Date: 2015
$20.00

Over the past several years, the Bureau of Reclamation’s Materials Engineering Research Laboratory has been developing and refining a test method to evaluate a coating’s resistance to erosion damage in sediment-laden immersion exposure. This test has initially been utilized as a screening/ranking method in selection of new coatings for the aforementioned severe service environments. 
Picture for Development Of A Tool To Track The Fraction Of Injected Water In Produced Water Streams
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Development Of A Tool To Track The Fraction Of Injected Water In Produced Water Streams

Product Number: 51323-19130-SG
Author: Thibaut V. J. Charpentier, Rose Lehman, Andre Leontieff
Publication Date: 2023
$20.00

Waterflooding is a common secondary recovery technique where injection water (IW) is used to maintain reservoir pressure and improve oil recovery. During such operations, the mobile hydrocarbon phase is displaced along with formation water (FW) toward producing wells. The resulting produced water stream is a blend of FW and IW; these waters can be incompatible resulting in dissolved ions to precipitate out of solution as mineral scale.
Picture for Development of a Versatile Continuous Application Based Corrosion Inhibitor to Mitigate Top-of-the-Line Corrosion under Both Sweet and Sour Operating Conditions
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Development of a Versatile Continuous Application Based Corrosion Inhibitor to Mitigate Top-of-the-Line Corrosion under Both Sweet and Sour Operating Conditions

Product Number: MECC23-19972-SG
Author: Jeremy Moloney
Publication Date: 2023
$20.00

Top-of-the-line corrosion (TLC) of carbon steel (CS) pipelines can be encountered during the transportation of wet gas under stratified flow conditions where temperature differences between the internal and external environments results in condensation of saturated vapors and water-wetted surface on the upper portion of the inside pipeline surface causing corrosion issues.1 Initially at least, the condensed water phase can be particularly corrosive with a low pH caused by dissolved acid gases (such as carbon dioxide and hydrogen sulfide) as well as organic acids in an unbuffered thin water film. Like bottom-of-the-line corrosion, TLC can be dominated by either carbon dioxide or hydrogen sulfide corrosion mechanisms.
Picture for Development of a Versatile Corrosion Inhibitor for Multiple Oil and Gas Operating Environments
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Development of a Versatile Corrosion Inhibitor for Multiple Oil and Gas Operating Environments

Product Number: 51319-13001-SG
Author: Jeremy Moloney
Publication Date: 2019
$20.00

Corrosion inhibition is the preferred choice of internal corrosion control of carbon steel pipelines and downhole tubulars for many oil and gas operators. The selection of a corrosion inhibitor (CI) is often system dependent because a CI that performs well under one set of conditions may not always do so under another. Thus throughout the world a huge number of CI products are available and deployed to attend to the wide and varied operating environments encountered in the oil and gas industry to mitigate carbon steel corrosion. Consequently this often requires operators to have to handle numerous chemical products to treat different fields and/or to replace CIs for the same asset as the field conditions change over time. Since this can pose challenges to operators from a logistical viewpoint it is advantageous for a CI to have a wide window of operability in order to help reduce the number of products an operator has to manage.A recent R&D effort has focused on the development of a highly versatile CI product which has been specifically formulated using a unique backbone of chemistries to inhibit carbon steel corrosion in a broad range of operating environments. Furthermore it has favourable product attributes to enable it to be handled and applied in many regions of the world via various application methods. Through a number of examples this paper demonstrates the high level of corrosion inhibition performance and adaptability of the newly developed CI product under a number of simulated field laboratory testing conditions including at low and high shears using sweet and sour gas mixtures and differing brine compositions and temperatures. The new product also demonstrates favourable secondary and physical properties in terms of low foaming and emulsion tendency good product stability at various temperatures as well as passing key assessments for application via umbilical and downhole capillaries. Keywords: carbon steel corrosion inhibitor sweet sour carbon dioxide hydrogen sulphide localised corrosion pitting
Picture for Development of a Water Ballast Tank Coating Monitoring System
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Development of a Water Ballast Tank Coating Monitoring System

Product Number: 51323-19320-SG
Author: Anders W. B. Skilbred, Kevin Farinholt, Erik Risberg, Fritz Friedersdorf
Publication Date: 2023
$20.00

Inspection of ballast tanks and enclosures is generally performed using traditional methods such as
visual inspection and non-destructive evaluation (NDE) techniques. However, it is common for these
methods to often be labor intensive and limited by physical restrictions that prohibit access to certain
areas. Further, the evaluation of the coating condition is heavily dependent on the inspector, and the
quality of the data gathered is varying.
Picture for Development of an Asphaltene Deposit Cleaning Technology using a QCMB tecnique
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Development of an Asphaltene Deposit Cleaning Technology using a QCMB tecnique

Product Number: 51319-12821-SG
Author: Kevin Janak
Publication Date: 2019
$20.00

Asphaltenes are a components of crude oil defined as a solubility class i.e. as a component of crude oil insoluble in n-pentane (C5 asphaltenes) or n-heptane (C7 asphaltenes) but soluble in aromatic solvents such as toluene and are complex polyaromatic macrocyclic structures with an overall varied composition. Asphaltene deposition remediation and inhibition are important considerations for flow assurance in upstream processes but methodologies to assess performance for cleaning purposes can provide variable results. We report on the development of a dispersant additive for aromatic solvent systems using a QCMB technique for evaluating the cleaning of a deposit. Further we report the performance of the additive in a case study and hence the utility of the technique to provide an assessment for potential field use.
Picture for Development Of An Efficient MIC Mitigation And Control Strategy In Pipelline Pigging Operations
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Development Of An Efficient MIC Mitigation And Control Strategy In Pipelline Pigging Operations

Product Number: 51322-17632-SG
Author: David Armstrong, Hejian Sun, Yuxiu Liu, Patrick Powell
Publication Date: 2022
$20.00

An operating company was concerned that its biocide and corrosion mitigation strategy was not sufficient to control corrosion in their pigging operations across the Gulf Coast of Texas. They provided water samples from several pigging access points that were heavily contaminated with SRBs, APBs, black deposits and oil. H2S was present in most of the samples suggesting a heavy presence of SRBs. They suspected that the black deposits were most likely FeS caused by the presence of microorganisms interacting with their pipelines. Indeed, culture vial tests (sometimes referred to as “bug bottles”) proved that the samples were heavily contaminated with microorganisms.
Picture for Development of an Electrochemical Method to Study Top-Of-The-Line Corrosion
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Development of an Electrochemical Method to Study Top-Of-The-Line Corrosion

Product Number: 51317--9106-SG
ISBN: 9106 2017 CP
Author: Md Mayeedul Islam
Publication Date: 2017
$20.00

A top-of-the-line monitoring cell has been developed, that measures in-situ corrosion rates by electrochemical methods. The data presented in this paper have been conducted over 5 days at variable condensation rates to evaluate the feasibility and accuracy of the methods applied.
Picture for Development of an F22 Metal Compatible Scale Inhibitor for Subsea Application
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Development of an F22 Metal Compatible Scale Inhibitor for Subsea Application

Product Number: 51323-19069-SG
Author: Chunfang Fan, Wei Zhang, Tiffany Nguyen, Jason Moses, Alexander Nelson, David Orta
Publication Date: 2023
$20.00

Mineral scale deposition is one of the major flow assurance issues for the oil and gas industry. When an oil or gas well produces water, there is the possibility that scale could form either by the mixing of incompatible waters forming oversaturated brine or by direct precipitation of the water that occurs naturally in reservoirs due to the changes in pressure, temperature, or pH. Scale inhibitors are commonly used to prevent mineral scale formation during oil and gas production and mitigate this flow assurance issue.
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