FUEL
·
2023
·
IF 7.4
Yang Liu,Chengxuan Wu,Xiaofang Lv,Hui Du,Qianli Ma,Chuanshuo Wang,Shidong Zhou,Bohui Shi,Shangfei Song,Jing Gong,Jimiao Duan
During deep-sea and ultra-deep-sea oil and gas exploitation, multiphase transmission lines are prone to be clogged by sediments produced by the various components in crude oils under extreme subsea conditions, such as hydrates, wax, resins, and asphaltenes. The pipelines face higher plugging risks when these deposits exist simultaneously. In order to elucidate the effects of wax and anti-agglomerants (AA) on hydrate growth and aggregation, microscopic morphology observation and cohesive force measurement of cyclopentane hydrate particles were conducted through a piece of equipment similar to the micromechanical force (MMF) apparatus. Results showed that in the low concentration of AA (0.05 wt%), hydrate particles experienced an approximately 10 % reduction in the profile area after converting water droplets to hydrate particles. Furthermore, the cohesive force between hydrate particles decreased from 8.57 ± 0.90 mN/m to 3.51 ± 0.43 mN/m as the AA concentration increased from 0.05 to 0.2 wt%. On the other hand, the presence of wax significantly altered the morphologies of hydrate particles. When wax coexisted with AA, the hydrate cohesive force was reduced by wax under low AA concentration (0.05 wt%) but increased under higher AA concentration. For a given concentration of AA, the hydrate cohesive force increased with the increasing wax content (from 0.1 to 0.3 wt%), indicating that wax crystals weakened the efficiency of AA, such as Span 80. Additionally, the effect of surface wetness of waxy hydrate particles on their cohesion was also investigated. The liquid bridge appeared between wet waxy hydrate particles, while the solid–solid contact existed between dry waxy hydrate particles. The cohesive force between dry waxy hydrate particles was smaller. Either liquid bridge or solid–solid contact that dominated hydrate cohesive force was affected by wax.
研究领域:
石油工程
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
FUEL
·
2023
·
IF 7.4
Zhiyuan Wang,Pengfei Li,Shikun Tong,Jianbo Zhang,Chenru Zhou,Jihao Pei,Hemin Yang,Chenwei Liu
The adhesion force between methane hydrate particles and wall droplets is an important reference for studying the behavior of hydrate particles accumulating or detaching from the tube wall. In this work, a high pressure visualization microscopic force testing system was built to evaluate the effect of hydrate anti-agglomerants (AAs) in the methane gas phase. It was found that the hydrate adhesion force reached its lowest value at the QAs1 solution concentration of 0.2 wt% (CMC), and the adhesion force was 589.81 mN/m under 1 subcooling condition and 1123.63 mN/m under 10 subcooling condition. It was found that the mechanism of QAs1 in reducing adhesion force under lower levels of subcooling conditions is mainly to reduce the gas–water interfacial tension. The mechanism of action of QAs1 in reducing adhesion force under higher levels of subcooling conditions is mainly due to the steric hindrance effect of QAs1 molecules. The presence of QAs1 molecules on the droplet surface leads to the slowdown of tangential growth of hydrate film and the slowdown of thickening of hydrate film, resulting in a reduction in adhesion force. When the concentration of QAs1 solution is higher than the CMC, the steric hindrance effect of QAs1 molecules is no longer enhanced with the increase of QAs1 solution concentration, while the presence of micelles makes the hydrate easier to nucleate and makes the adhesion force gradually increase. These research data are useful to study the mechanism of action of quaternary ammonium salts as hydrate anti-agglomerants (AAs) and provide a basis for determining the optimal amount of additives for AAs used to prevent hydrate accumulation in natural gas pipelines, and for optimizing hydrate prevention solutions in deep-water gas wells.
研究领域:
化学工程
·
能源科学
✓ 已验证
DOI
高影响因子
FUEL
·
2023
·
IF 7.4
Pengfei Li,Shikun Tong,Jihao Pei,Jianbo Zhang,Yukun Guo,Xiao Liu,Weiqi Fu,Zhiyuan Wang
Hydrate aggregation and deposition on the pipe wall are the main causes of hydrate plugging in pipelines. Microscopic forces between hydrate particles are an important reference for determining the behavior of aggregation or separation from the pipe wall of hydrate particles. Based on a high-pressure visual micro-force measurement system, this study measured the hydrate particle-hydrate particle cohesive force and hydrate particle–wall liquid droplet adhesion force under pure water, as well as hydrate particle–wall liquid droplet adhesion force under anti-agglomerants (AAs). It was found that the magnitude of hydrate particle-hydrate particle cohesive force was ×10 mN/m, and the magnitude of hydrate particle–wall liquid droplet adhesion force was ×10 3 mN/m. The effects of 4 AAs in the methane gas-dominated system were evaluated from a micro-perspective, revealing that after adding DDBAB, D1021, AEO-9, and CDEA, the maximum reduction of adhesion force was 67%, 64%, 51%, and 53% compared with that under pure water, respectively. The mechanism of AAs reducing adhesion force was further explored, revealing that the adhesion force arose from a liquid bridge and was affected by the gas–water interfacial tension of solutions at low subcoolings. While at high subcoolings, the force was determined by the combined force of the liquid bridge and the hydrate shell. The addition of AAs reduced the gas–water interfacial tension of solutions, and the steric hindrance effect of AA molecules also weakened the tensile strength of the hydrate shell, leading to a decreased adhesion force. These experimental data can help deepen our understanding of the microscopic forces between methane hydrate particles, and provide experimental data and scheme design basis for wellbore flow assurance of deepwater gas wells.
研究领域:
石油工程
·
化学工程
✓ 已验证
DOI
高影响因子
Frontiers in Energy Research
·
2022
·
IF 3.858
Li Xufeng,Meng Zilong
Gas hydrate is a type of ice like crystals, which could widely form and plug the offshore oil and gas pipelines. In order to reduce the cost of hydrate control in oil and gas transportation, search for new anti-agglomerates (AAs) is always needed. In this work, fourteen different types of polymers from drilling fluid additives were selected and their anti-agglomeration ability on gas hydrate was experimentally studied by using a high-pressure rocking cell. The hydrate volume percentage, slider moving range, and moving velocity were measured for evaluation. Two polymers [acrylamide polymer (AAP) and hydrolyzed polyacrylonitrile ammonium salt (HAPS)] were found to be effective to avoid agglomerating at low hydrate concentration (≤6%). AAP and HAPS could prevent plugging, while the hydrate concentration is lower than 15.12% and 16.92%, respectively. It was speculated that the hydrogen bonding capability of the hydrophilic groups, the length of the hydrophobic chains and polymer molecules, and the antagonism of different functional groups might affect the anti-agglomerating performance of polymers.
研究领域:
化学工程
·
石油工程
✓ 已验证
产品关联
DOI
高影响因子
ENERGY & FUELS
·
2022
·
IF 4.654
Changhong Yu,Cheng Yue,Baojiang Sun,Xin Yang,Jiakai Ji,Zilong Meng,Litao Chen
Hydrate can easily form and cause plugging in offshore oil and gas pipelines. As the managing strategy moves from full avoidance to dynamic control, antiagglomerants (AAs) could be an economical and efficient option for hydrate management. Searching for new efficient hydrate AAs is always needed. In this work, the antiagglomerating performances of 57 commercial chemicals, including cationic surfactants, zwitterionic surfactants, nonionic surfactants, and polymers, to methane hydrate in an oil–gas–water system were evaluated by using a rocking-cell apparatus. The slider-moving trajectories were recorded during hydrate formation. The performances of AAs were evaluated based on the slider-moving profiles at various hydrate fractions. It was found that cocamidopropyl dimethylamine, a nonionic surfactant that is labeled as an A class AA, could fully avoid hydrate plugging when the hydrate fraction was under 18.76%. The slider-moving trajectory in the full range of the cell indicated that the hydrate was well-dispersed in the liquid phase. Besides, 23 chemicals mainly from cationic and zwitterionic surfactants, which are labeled as B class AAs, could partially avoid hydrate plugging at various hydrate fractions (10.96–19.92%). The slider could move in a partial range of the cell, indicating that the hydrate may agglomerate and accumulate at the end of the cell. The rest of the chemicals were labeled as class C AAs, with which the slider was fully stuck. The working mechanism is discussed for an insightful understanding on the antiagglomerating performances of the screened AAs. Chemicals with a combined presence of an amide group and an amine group exhibit great potential for hydrate antiagglomeration, while the hydrogen-bonding ability of the hydrophilic amine headgroup may be adversely affected by the incorporation of anions.
研究领域:
化学工程
·
能源科学
·
材料科学
✓ 已验证
DOI
高影响因子
MOLECULES
·
2025
·Vol. 30
·期 2
·308
·
IF 4.6
Sunan Wang,Litao Chen,Lei Guo,Jiansheng Luo,Liangliang Ren,Xiong Xiang,Tie Geng,Changhong Yu,Zilong Meng
The hydrate blockage avoidance performance of two anti-agglomerants (coconut amidopropyl dimethylamine, propylene bis (octadecylamidopropyl dimethylammonium chloride)) and their mixtures with polyvinylpyrrolidone (PVP) was tested in a high-pressure rocking cell apparatus. The effect of gas–liquid ratio, water content and PVP concentration were analyzed. A method for evaluating the kinetic inhibiting and anti-agglomerating performance of hydrate inhibitors was established. It was found that coconut amidopropyl dimethylamine had good anti-agglomerating performance at a low gas–liquid ratio (0.5) and various water content levels (20~80%), while propylene bis (octadecylamidopropyl dimethylammonium chloride) had a good anti-agglomerating performance only at a low gas–liquid ratio (0.5) and high water content (80%), and the hydrate volume fraction was up to 23.27% for good anti-agglomeration. When PVP was mixed with the above two anti-agglomerants, it was found that coconut amidopropyl dimethylamine could significantly reduce the kinetic inhibition performance of PVP, while propylene bis (octadecylamidopropyl dimethylammonium chloride) had no significant effect on the kinetic inhibition performance of PVP. The maximum subcooling was 4.4 °C. PVP had no significant effect on the anti-agglomerating performance of the two anti-agglomerants, and the maximum hydrate volume fraction was 18.87% when the agglomeration was well inhibited.
研究领域:
化学工程
·
石油工程
✓ 已验证
DOI
PubMed
高影响因子
危险品化学品经营许可证（带存储）