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Development Of Fes Scale Control Technology Using Polymeric Dispersants In Sour Environment

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Mineral scales frequently occur in tanks, pipelines, cooling and heating system, production wells of
oil and gas, external and internal membrane, and other equipment during industrial processes,
causing the reduction of process efficacy and millions of dollars on dealing with the scale issues. As
oil and gas are produced increasingly in more unconventional reservoirs, such as deeper and tighter
zones, with new technologies, more challenges are encountered to mitigate scale problems.

Product Number: 51322-17630-SG
Author: Saebom Ko, Zhaoyi Dai, Xin Wang, Amy T. Kan, Wei Lee, Mason B. Tomson
Publication Date: 2022
Industries: Corrosion Monitoring and Control , Coatings and Linings , Coatings
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When hydrogen sulfide gas is evolved in the presence of iron from various corrosion processes in
downhole, iron sulfide can quickly precipitate. In the recent year, sulfide scale issues have been
drawing lots of attention. Firstly, iron sulfide is one of the most or significantly unsolved deposition problem in oil and gas production. Secondly, iron sulfide has oleophilic nature so that it can be difficult to separate iron sulfide from oil phase during production processes. Polymeric dispersants have exhibited their feasibility to prevent the deposition of iron sulfide scales, but dispersants have not been widely validated to control FeS scale problems and limited numbers of trials and reports have been available. The goals of this study were (1) to develop efficient and effective technology preventing iron sulfide particle deposition on the surface as well as maintaining iron sulfide in the water phase; and (2) to understand FeS scale controlling reaction mechanism. Our studies indicate that carboxymethycellulose (CMC) displays the excellent performance of iron sulfide dispersion in pH 4.3 – 6.7, temperature 70 – 90 °C, and FeS saturation index (SI) 0.13 – 1.27. At pH 5.2, the required minimum CMC concentration to disperse FeS particles (Ccrit) was 20 mg/L at 70 °C and SI(FeSm) = 0.54 and 40 mg/L at 90 °C and SI(FeSm) = 0.59. As pH increased to 6.7 at 70 °C, Ccrit was reduced to 5 mg/L at SI (FeSm) = 1.27. On the other hand, Ccrit significantly increased to 100 mg/L at SI (FeSm) = 0.13 and 400 mg/L at SI(FeSm) = 0.44 at pH 4.3 and 70 °C. Hydrodynamic particle sizes remained in nano size in different CMC concentrations in ranges of 300 to 530 nm at pH 4.3 and 170 to 335 nm at pH 5.0. The combination of DTPMP and CMC displayed synergistic effect. The greater portion of FeS particles were dispersed and kept their size smaller in the combination of DTPMP and CMC than CMC by itself. But it became less effective at 90 °C to inhibit or disperse iron sulfide solid formation than at 70 °C. FeS particles remained in water phase in the presence of CMC, while they stayed in oil phase in the absence of CMC.

When hydrogen sulfide gas is evolved in the presence of iron from various corrosion processes in
downhole, iron sulfide can quickly precipitate. In the recent year, sulfide scale issues have been
drawing lots of attention. Firstly, iron sulfide is one of the most or significantly unsolved deposition problem in oil and gas production. Secondly, iron sulfide has oleophilic nature so that it can be difficult to separate iron sulfide from oil phase during production processes. Polymeric dispersants have exhibited their feasibility to prevent the deposition of iron sulfide scales, but dispersants have not been widely validated to control FeS scale problems and limited numbers of trials and reports have been available. The goals of this study were (1) to develop efficient and effective technology preventing iron sulfide particle deposition on the surface as well as maintaining iron sulfide in the water phase; and (2) to understand FeS scale controlling reaction mechanism. Our studies indicate that carboxymethycellulose (CMC) displays the excellent performance of iron sulfide dispersion in pH 4.3 – 6.7, temperature 70 – 90 °C, and FeS saturation index (SI) 0.13 – 1.27. At pH 5.2, the required minimum CMC concentration to disperse FeS particles (Ccrit) was 20 mg/L at 70 °C and SI(FeSm) = 0.54 and 40 mg/L at 90 °C and SI(FeSm) = 0.59. As pH increased to 6.7 at 70 °C, Ccrit was reduced to 5 mg/L at SI (FeSm) = 1.27. On the other hand, Ccrit significantly increased to 100 mg/L at SI (FeSm) = 0.13 and 400 mg/L at SI(FeSm) = 0.44 at pH 4.3 and 70 °C. Hydrodynamic particle sizes remained in nano size in different CMC concentrations in ranges of 300 to 530 nm at pH 4.3 and 170 to 335 nm at pH 5.0. The combination of DTPMP and CMC displayed synergistic effect. The greater portion of FeS particles were dispersed and kept their size smaller in the combination of DTPMP and CMC than CMC by itself. But it became less effective at 90 °C to inhibit or disperse iron sulfide solid formation than at 70 °C. FeS particles remained in water phase in the presence of CMC, while they stayed in oil phase in the absence of CMC.

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Picture for Development Of High Velocity Oxygen Fuel (HVOF) Corrosion Resistant Coatings; A Comparison Between Novel High Entropy Alloy (HEA) And Conventional Cermet Coatings For Geothermal Applications
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Development Of High Velocity Oxygen Fuel (HVOF) Corrosion Resistant Coatings; A Comparison Between Novel High Entropy Alloy (HEA) And Conventional Cermet Coatings For Geothermal Applications

Product Number: 51322-17675-SG
Author: Gifty Oppong Boakye, Baldur Geir Gunnarsson, Erlend Oddvin Straume, Feifei Zhang, Arna María Ormsdóttir, Sigrún Nanna Karlsdóttir
Publication Date: 2022
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Several components in geothermal power plants need to be protected from the environment due to the corrosive nature of geothermal fluids used to generate the energy. Depending on the fluid properties for any location, the type of protection varies. In geothermal power plants, wear, erosion, corrosion, and scaling are all known problems1. These issues can lead to a variety of outcomes, ranging from decreased plant efficiency to upstream component failure. Failure of a component is thus a significant challenge in the geothermal industry, where materials need to operate in high temperature and high pressure environments. A major cost factor is also linked to the drilling of geothermal wells, where cost rises due to increased depth/distance of drilling, increased trip times, higher high temperature and high-pressure conditions which can lead to increased wear and corrosion of the materials. To address the issue, coatings can be considered to be a potential solution to extend the service life of downhole equipment.
Picture for Development Of A F22 Compatible Scale Inhibitor
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Development Of A F22 Compatible Scale Inhibitor

Product Number: 51322-17610-SG
Author: Ya Liu, Benton Hutchinson, Rose Lehman, Jeffrey Russek, James Outlaw
Publication Date: 2022
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F22 is a low alloy steel that typically contains 12% Carbon, 2.25% Chromium, and 1.0% Molybdenum1. This steel has been widely used in oil production systems, especially in well head design and construction. As a low alloy steel, F22 can be corroded by oilfield chemicals under certain circumstances. For example, it was observed in the Gulf of Mexico that typical scale inhibitor chemistries caused severe corrosion on F22.
Picture for Design Of Sour Service Material: Combining Metallurgical Design, Laboratory And Full Scale Testing Towards A Novel High Strength Sour Service Material
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Design Of Sour Service Material: Combining Metallurgical Design, Laboratory And Full Scale Testing Towards A Novel High Strength Sour Service Material

Product Number: 51322-17615-SG
Author: Michel PIETTE, Florian THEBAULT, John FORTAILLIER, Livia-Raquel CUPERTINO-MALHEIROS
Publication Date: 2022
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During the last decades, low alloyed steels with improved resistance to Sulfide Stress Cracking (SSC) have been developed for covering specific applications as heavy wall casings1 or expandable tubings2 or for reaching higher mechanical properties, such as 125 ksi Specified Minimum Yield Strength (SMYS) materials.3-6 For the latter, relevant sour environments for developed grades are mild, meaning that all sour applications cannot be covered while a strong interest exists for O&G operators to use high strength materials when designing wells. Consequently, there is an incentive to push the limits of use of high strength sour service steels by enhancing their resistance to SSC. Several recommendations were already published when designing high strength sour service grades: hardness level shall be limited as much as possible and be preferentially below 22 HRC7, microstructure shall present a minimum required amount of martensite8 which is well known to be ideal for combining high mechanical properties and high resistance to hydrogen. Besides, many authors highlighted some other influencing parameters related to the material or the process.
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