Studies on some zwitterionic surfactant gas hydrate anti-agglomerants

Kelland, Malcolm A.; Svartaas, Thor M.; Øvsthus, Jorunn; Tomita, Takashi; Chosa, Jun-ichi

doi:10.1016/j.ces.2006.02.003

Cited by 75 publications

(45 citation statements)

References 2 publications

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“…The synthesized polyDMHAMs are summarized in Table 1. 14 (4). To a Schlenk tube equipped with a Young's tap and a magnetic stirring bar were added VCap (3, 0.7 g, 5.03 mmol) and aqueous isopropyl alcohol (10 mL).…”

Section: Methodsmentioning

confidence: 99%

N,N-Dimethylhydrazidoacrylamides. Part 2: High-Cloud-Point Kinetic Hydrate Inhibitor Copolymers with N- Vinylcaprolactam and Effect of pH on Performance

Mady

Kelland

2015

Energy Fuels

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Poly(N,N-dimethylhydrazidoacrylamides)s (PDMHAMs) and a series of copolymers of (N,N-dimethylhydrazidoacrylamide) and (N-isopropylacrylamide) were recently investigated as kinetic hydrate inhibitors (KHIs). Poly(Nvinylcaprolactam) (PVCap) and related copolymers have been used as a class of commercial KHIs in the oil and gas industry to prevent plugging of pipelines with gas hydrates. In this study, we have synthesized and investigated the ability of copolymers of DMHAM monomer and VCap monomer to inhibit structure II gas hydrate formation in high-pressure rocking cells at approximately 75 bar. Various polymer molecular weights have been investigated at various pH conditions. It was found that the novel polymers have high cloud points in deionized (DI) water or brine solutions at high or low pH under pressure compared to polyVCap. A 1:2 copolymer of DMHAM/VCap gave the best KHI performance for this class of copolymer with a cloud point at 50°C in DI water. Also, a 1:1 DMHAM/VCap copolymer gave excellent KHI performance, as well as giving no cloud point up to 100°C in DI water or high-salinity solutions (3.6−15 wt % NaCl) at pH 5.0. The cloud point was found to be 67°C at pH 12.0 for the 15 wt % NaCl solution, making it compatible for use in high-salinity water-based deep-water drilling fluids. It was also found that high pH improved the performance of the KHIs compared to otherwise identical tests at pH 5.0. This may be related to removing the structure I (SI)-forming and relatively more soluble acid gas CO 2 from the system at high pH.

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Section: Methodsmentioning

confidence: 99%

N,N-Dimethylhydrazidoacrylamides. Part 2: High-Cloud-Point Kinetic Hydrate Inhibitor Copolymers with N- Vinylcaprolactam and Effect of pH on Performance

Mady

Kelland

2015

Energy Fuels

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“…Subsequently, Shell found that the quaternary ammonium surfactant was an ideal agglomeration inhibitor and argued that two or more n-butyl, n-pentyl or isopentyl ammonium salts had a good performance of delaying hydrate crystal growth [16]. In addition, the BJ UnichemCompany found that quaternized polyamine polyethers are more efficient than polyvinyl caprolactam (PVCap) and some quaternary anti-agglomerants in preventing the accumulation of tetrahydrofuran hydrate [16,17]. However, most of these anti-agglomerants are used for preventing CH 4 hydrate blockage and must be used in high-ratio oil/water systems (70 vol %), which tend to produce grease in the pipeline.…”

Section: Introductionmentioning

confidence: 99%

Anti-Agglomerator of Tetra-n-Butyl Ammonium Bromide Hydrate and Its Effect on Hydrate-Based CO2 Capture

Chen

et al. 2018

Energies

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Tetra-n-butyl ammonium bromide (TBAB) was widely used in the research fields of cold storage and CO 2 hydrate separation due to its high phase change latent heat and thermodynamic promotion for hydrate formation. Agglomeration always occurred in the process of TBAB hydrate generation, which led to the blockage in the pipeline and the separation apparatus. In this work, we screened out a kind of anti-agglomerant that can effectively solve the problem of TBAB hydrate agglomeration. The anti-agglomerant (AA) is composed of 90% cocamidopropyl dimethylamine and 10% glycerol, which can keep TBAB hydrate of 19.3-29.0 wt. % in a stable state of slurry over 72 h. The microscopic observation of the morphology of the TBAB hydrate particles showed that the addition of AA can greatly reduce the size of the TBAB hydrate particles. CO 2 gas separation experiments found that the addition of AA led to great improvement on gas storage capacity, CO 2 split fraction and separation factor, due to the increasing of contact area between gas phase and hydrate particles. The CO 2 split fraction and separation factor with AA addition reached up to 70.3% and 42.8%, respectively.

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“…In deep water operations, adding methanol as 10-15% of the weight of the water content of a hydrocarbon production stream may be necessary and indeed is common (Kelland et al, 2006a;Xiao and Adidharma, 2009). Accordingly, methanol requirements increase if fractional water cuts increase during production (Makogon and Sloan, 2002).…”

Section: Methanolmentioning

confidence: 99%

“…Three conditional requirements further limit KHI operational use in oilfield pipelines: (1) a natural gas pipeline or subsea production line must have no liquid hydrocarbon phase (Kelland et al, 2006a). (2) Treated wells or subsea lines must not be shut-in for appreciable periods because KHIs then lose their effectiveness.…”

Section: Limitations To Use Of Khismentioning

confidence: 99%

Hydrate Inhibition During Drilling and Production

Rogers¹

2015

Offshore Gas Hydrates

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Studies on some zwitterionic surfactant gas hydrate anti-agglomerants

Cited by 75 publications

References 2 publications

N,N-Dimethylhydrazidoacrylamides. Part 2: High-Cloud-Point Kinetic Hydrate Inhibitor Copolymers with N- Vinylcaprolactam and Effect of pH on Performance

N,N-Dimethylhydrazidoacrylamides. Part 2: High-Cloud-Point Kinetic Hydrate Inhibitor Copolymers with N- Vinylcaprolactam and Effect of pH on Performance

Anti-Agglomerator of Tetra-n-Butyl Ammonium Bromide Hydrate and Its Effect on Hydrate-Based CO2 Capture

Hydrate Inhibition During Drilling and Production

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