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Picture for 51317-9586- Polymer and Nanomaterial Based Inhibitors: Stimuli-Responsive
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51317-9586- Polymer and Nanomaterial Based Inhibitors: Stimuli-Responsive

Product Number: 51317-9586-SG
ISBN: 9586 2017 CP
Author: Rigoberto C. Advincula
Publication Date: 2017
$20.00

Principles and work investigating various corrosion and scaling inhibitors for the production and process industries. The use of block-copolymers and hyperbranched oligomeric design in inhibitors is of a high interest.  Also involved are a number of analytical and testing methods
Picture for Oil and Gas Field Corrosion Inhibitor Performance Validation Implementation of EIS
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51318-10636-Oil and Gas Field Corrosion Inhibitor Performance Validation Implementation of EIS

Product Number: 51318-10636-SG
Author: J. Sonke / W.M. Bos
Publication Date: 2018
$20.00

Results, interpretation, benefits and limits of using electrochemical impedance spectroscopy (EIS). Results reveal CI protection/failure mechanisms under specific test conditions.
Picture for Modeling Mineral Scaling in Oil and Gas Environments up to Ultra High Pressures and Temperatures
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51318-10828-Modeling Mineral Scaling in Oil and Gas Environments up to Ultra High Pressures and Temperatures

Product Number: 51318-10828-SG
Author: M.M. Lencka, R.D. Springer, P. Wang and A. Anderko
Publication Date: 2018
$20.00

To address the need to predict scaling at conditions ranging from ambient to extreme, a thermodynamic model has been developed to represent the solubility of scaling minerals at temperatures up to 300 °C and pressures up to 1,700 atmospheres.
Picture for Scaling-resistant coatings for high temperature sour gas service
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51318-11538-Scaling-resistant coatings for high temperature sour gas service

Product Number: 51318-11538-SG
Author: Lawrence Kool / Hui Zhu / Qilang Wang / Fakuen Chang
Publication Date: 2018
$20.00

This paper describes the development of novel coating materials and methods and evaluation of their effectiveness in preventing iron sulfide scale.
Picture for Coatings To Regulate Scaling In Geothermal Applications
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Coatings To Regulate Scaling In Geothermal Applications

Product Number: 51322-17547-SG
Author: Alexandre Sabard, Shiladitya Paul, Briony Holmes, Namrata Kale, Paolo Taddei Pardelli, Claretta Tempesti, Andrea Mannelli, Ural Halaçoğlu, Hakan Alp Sahiller, Raziye Şengün, Sylvie Rouge, Nadia Caney, Andri Stefansson, Per Kjellgren, , Jan Přikryl, Volkan Ediger, Gokhan Kirkil
Publication Date: 2022
$20.00

Geothermal Energy is currently engineered as an “always on” baseload supply, due to the limited flexibility to throttle the well without scaling and fatigue issues, and it is engineered for maximal efficiency at this output level. Scaling is a major problem in geothermal plants, particularly in cases where the geothermal fluid composition and plant operation make it difficult to control scaling. In such areas, particularly where scale inhibitors cannot be employed, the formation of scales can make the process less efficient and in extreme cases can lead to unexpected shutdown.
Picture for Hydrogeochemical Modelling to Monitor Scaling and Corrosion during Geothermal Energy Production
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Hydrogeochemical Modelling to Monitor Scaling and Corrosion during Geothermal Energy Production

Product Number: 51317--9044-SG
ISBN: 9044 2017 CP
Author: Helmuth Sarmiento Klapper
Publication Date: 2017
$20.00

Suitability and potential benefit of using hydrogeochemical modelling to monitor scaling and corrosion during geothermal exploration and production in the high-salinity geothermal area of the North German Basin was explored.
Picture for Methodologies to Evaluate Corrosion of Carbon and Stainless Steels in Artificial Geothermal Solutions
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Methodologies to Evaluate Corrosion of Carbon and Stainless Steels in Artificial Geothermal Solutions

Product Number: 51324-20716-SG
Author: Gabriela Aristia; Sabrina Marcelin; Nicolas Mary; Gaurav R. Joshi; Francois Grosjean
Publication Date: 2024
$40.00
Corrosion and scaling are some of the most common challenges in geothermal applications due to the complex brine chemistry combined with the high temperatures and pressures, and the gaseous components. To study mineral scaling at metallic surfaces, appropriate corrosion tests representing the real geothermal reservoir and operating conditions must be selected. This paper focus on the reconstruction of thermal gradients between geothermal fluids and the steel walls of wells and heat exchanger tubes, in laboratory and autoclave flow loop tests (up to 200°C and 300 bar), to simulate scaling and corrosion conditions. The implementation of an electrochemical measurement device makes it possible to monitor changes to the electrochemical behaviour of steel subjected to thermal gradients in these environments and so the corrosion response and in situ evolution of scales. Results from carbon steels (N80 and P110) and stainless steel (13Cr) in artificial geothermal brines representative of Dogger and Soultz geothermal wells in France are presented.
Picture for Silica Solubility in High Enthalpy Water up to 440°C in the Presence of NaCl
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Silica Solubility in High Enthalpy Water up to 440°C in the Presence of NaCl

Product Number: 51324-21029-SG
Author: Morten Tjelta; Sissel Opsahl Viig
Publication Date: 2024
$40.00
In geothermal energy production, precipitation/scaling and potential plugging of wells is one of the major threats to flow assurance. Mitigation strategies should be considered at the design stage, but to do so knowledge about solubility across a relevant space of temperature, pressure and fluid composition is needed. In hot fluids, silica scaling is often found to be the major concern. Predictive models available in literature give good agreement with experimental values in the region where data are available, but there is limited data available at high temperatures and low pressures, in particular in the presence of salt. This work describes an experimental setup designed to carry out solubility experiments up to 500 °C and 400 bar. A main feature of the setup is the ability to dilute the sample fluid in the hot zone in order to avoid precipitation during sampling. Illustrations are given for how existing phase relations can be used to guide the execution of such high-pressure high-temperature experiments. Results of silica solubility experiments in the presence of NaCl up to 440 °C at 150-350 bar are presented. This work includes data at the steam side pseudocritical line (critical density isochor) where limited data is available in the literature. The experimental concept, with hot zone dilution to avoid precipitation during sampling, can be used to obtain fluid samples as a function of time. Although utilized in the current work for solubility experiments it should be equally applicable to corrosion studies.
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