Kinetic Hydrate Inhibition Performance of MEG in Under-Inhibition System: Reduction Opportunities of MEG Injection for Offshore Gas Field Developments

Kim, Jakyung; Shin, Kyuchul; Kim, Juneyoung; Chang, Daejun; Seo, Yutaek; Chang, Kwang Pil

doi:10.2118/24961-ms

Cited by 9 publications

(8 citation statements)

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“…This MEG concentration reflects average MEG concentrations inside the gas pipeline. Usually, lean MEG (90 wt %) gets diluted by produced water to below 40%. − …”

Section: Methodsmentioning

confidence: 99%

Analytical Techniques for Analyzing Thermally Degraded Monoethylene Glycol with Methyl Diethanolamine and Film Formation Corrosion Inhibitor

AlHarooni¹,

Pack²,

Iglauer³

et al. 2016

Energy Fuels

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Gas hydrate formation and corrosion within gas pipelines are two major flow assurance problems. Various chemical inhibitors are used to overcome these problems, such as monoethylene glycol (MEG) for gas hydrate control and methyl diethanolamine (MDEA) and film formation corrosion inhibitor (FFCI) for corrosion control. As an economical solution, MEG is regenerated due to the large volume required in the field. MEG regeneration involves thermal exposure by traditional distillation to purify the MEG. During this process, MEG is subjected to thermal exposure and so might be degraded. This study focuses on evaluating six analytical techniques for analyzing the degradation level of various MEG solutions consisting of MDEA and FFCI that were thermally exposed to 135 °C, 165 °C, 185 °C, and 200 °C. The analytical techniques evaluated are pH measurement, electrical conductivity, change in physical characteristics, ion chromatography (IC), high performance liquid chromatography–mass spectroscopy (HPLC-MS), and gas hydrate inhibition performance (using 20 wt % MEG solutions with methane gas at pressure from 50 to 300 bar). Most of the analytical techniques showed good capability, while electrical conductivity showed a poor result for solution without MDEA and IC showed poor results for solution exposed to 135 and 165 °C. The primary aim of this paper is thus to provide the industry with a realistic evaluation of various analytical techniques for the evaluation of degraded MEG solutions and to draw attention to the impact of degraded MEG on gas hydrate and corrosion inhibition as a result of the lack of quality control.

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“…This MEG concentration reflects average MEG concentrations inside the gas pipeline. Usually, lean MEG (90 wt %) gets diluted by produced water to below 40%. − …”

Section: Methodsmentioning

confidence: 99%

Analytical Techniques for Analyzing Thermally Degraded Monoethylene Glycol with Methyl Diethanolamine and Film Formation Corrosion Inhibitor

AlHarooni¹,

Pack²,

Iglauer³

et al. 2016

Energy Fuels

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“…2,7,8 The KHIs have also, in many cases, been used together with THIs to decrease the large amounts of chemicals needed to obtain sufficient inhibition. 9,10 The majority of oil and gas fields produce natural gas mixtures that lead to structure II (SII) gas hydrate as the most thermodynamically stable phase. 3 That is why studies on developing KHIs have concentrated on using a SII-forming gas mixture.…”

Section: ■ Introductionmentioning

confidence: 99%

Comparison of Kinetic Hydrate Inhibitor Performance on Structure I and Structure II Hydrate-Forming Gases for a Range of Polymer Classes

Abrahamsen

Kelland

2018

Energy Fuels

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A series of water-soluble polymers has been investigated for comparison of their potential as kinetic hydrate inhibitors (KHIs) for both structure I (SI)- and structure II (SII)-forming gas mixtures. A slow constant cooling test method and steel rocking cells have been used for these experiments. The average hydrate onset temperatures (T o) have been used to rank the polymers according to their KHI ability, with the lower T o values giving a higher rank. The object of the study was a comparison of the KHI performance for SI versus SII inhibition for a range of polymers and not a study to find the optimal polymer for each hydrate structure. The most interesting comparative results were the large deviations of the ethyl derivative of poly(N-alkylglycine) for the two hydrate systems, where this polymer performed very well with the SI-forming gas but had significantly less effect on the SII-forming gas. Also, poly(2-ethyl-2-oxazoline) (PEtOx) and poly(isopropenyloxazoline)-01 (PiPOx-01) ranked better with SI hydrates in comparison to the SII hydrate system. In general, the polymers that work well on the SI-forming gas work well on the SII-forming gas as well. KHI mechanistic insights from this study were discussed. Although other KHIs outside this study may be available with better performance, we found that the best KHIs for SII hydrates were two N-vinylcaprolactam polymers in the synergistic solvent 2-butoxyethanol, and the best KHIs for SI hydrates were a N-isopropylacrylamide homopolymer and the same two N-vinylcaprolactam polymers.

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“…Seven mL (≈11% volume of the cell) of the diluted samples was injected into the sapphire cell. This MEG concentration was selected to represent the average solution concentrations inside the gas pipeline during field start-up with high water cut, as the lean MEG is diluted by the produced water to below 40%. ,,, …”

Section: Methodsmentioning

confidence: 99%

“…This MEG concentration was selected to represent the average solution concentrations inside the gas pipeline 53 during field start-up with high water cut, 54 as the lean MEG is diluted by the produced water to below 40%. 18,50,55,56 2.3. Scenarios.…”

Section: Energy and Fuelsmentioning

confidence: 99%

Influence of Regenerated Monoethylene Glycol on Natural Gas Hydrate Formation

et al. 2017

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The key objective of this study is to investigate the efficiency of thermodynamic hydrate inhibition of monoethylene glycol (MEG) solutions collected from a MEG regeneration/reclamation pilot plant, simulating six scenarios of the start-up and clean-up phases of a typical gas field. The scenarios contain complex solutions of condensates, drilling muds/well completion fluids with high concentrations of divalent–monovalent ions, particulates, and various production chemicals, which can result in various system upsets in a MEG plant. MEG was regenerated and reclaimed at a recently constructed closed-loop MEG pilot plant that replicates a typical field plant. During MEG plant operation, feed-rich MEG is separated, cleaned, and heated so that water in it is evaporated and purified for reuse. In this study, equilibrium conditions of natural gas hydrates in the presence of 20 wt % of regenerated and reclaimed MEG solution at a pressure range of 65–125 bar were reported. The equilibrium data were measured in a PVT sapphire cell unit using an isochoric temperature search method. The measured data were compared with the literature and theoretical predictions to investigate the influence of regenerated/reclaimed MEG on gas hydrate inhibition performance. A better understanding of the efficiency of regenerated complex MEG solutions on hydrate phase equilibria forms a basis for improved system design, operations, and calculating required MEG dosages for hydrate inhibition.

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Kinetic Hydrate Inhibition Performance of MEG in Under-Inhibition System: Reduction Opportunities of MEG Injection for Offshore Gas Field Developments

Cited by 9 publications

References 0 publications

Analytical Techniques for Analyzing Thermally Degraded Monoethylene Glycol with Methyl Diethanolamine and Film Formation Corrosion Inhibitor

Analytical Techniques for Analyzing Thermally Degraded Monoethylene Glycol with Methyl Diethanolamine and Film Formation Corrosion Inhibitor

Comparison of Kinetic Hydrate Inhibitor Performance on Structure I and Structure II Hydrate-Forming Gases for a Range of Polymer Classes

Influence of Regenerated Monoethylene Glycol on Natural Gas Hydrate Formation

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