Mechanism and control factors of hydrate plugging in multiphase liquid-rich pipeline flow systems: A review

doi:10.1007/s11708-022-0830-z

Front. Energy

2022, Vol. 16

Issue (5) : 747-773 https://doi.org/10.1007/s11708-022-0830-z

REVIEW ARTICLE

Mechanism and control factors of hydrate plugging in multiphase liquid-rich pipeline flow systems: A review

Shuwei ZHANG¹, Liyan SHANG²(

), Zhen PAN¹, Li ZHOU³, You GUO⁴

¹. College of Petroleum Engineering, Liaoning Petrochemical University, Fushun 113001, China
². College of Environmental and Safety Engineering, Liaoning Petrochemical University, Fushun 113001, China
³. College of Petrochemical Technology, Liaoning Petrochemical University, Fushun 113001, China
⁴. Fushun City Special Equipment Supervision and Inspection Institute, Fushun 113001, China

Download: PDF(8439 KB) HTML
Export: BibTeX | EndNote | Reference Manager | ProCite | RefWorks

Abstract

There is nothing illogical in the concept that hydrates are easily formed in oil and gas pipelines owing to the low-temperature and high-pressure environment, although requiring the cooperation of flow rate, water content, gas-liquid ratio, and other specific factors. Therefore, hydrate plugging is a major concern for the hydrate slurry pipeline transportation technology. In order to further examine potential mechanisms underlying these processes, the present paper listed and analyzed the significant research efforts specializing in the mechanisms of hydrate blockages in the liquid-rich system, including oil-based, water-based, and partially dispersed systems (PD systems), in gathering and transportation pipelines. In addition, it summarized the influences of fluid flow and water content on the risk of hydrate blockage and discussed. In general, flow rate was implicated in the regulation of blockage risk through its characteristic to affect sedimentation tendencies and flow patterns. Increasing water content can potentiate the growth of hydrates and change the oil-water dispersion degree, which causes a transition from completely dispersed systems to PD systems with a higher risk of clogging. Reasons of diversity of hydrate plugging mechanism in oil-based system ought to be studied in-depth by combining the discrepancy of water content and the microscopic characteristics of hydrate particles. At present, it is increasingly necessary to expand the application of the hydrate blockage formation prediction model in order to ensure that hydrate slurry mixed transportation technology can be more maturely applied to the natural gas industry transportation field.

Keywords hydrate flow rate water content mechanism of pipeline blockage rich liquid phase system

Corresponding Author(s): Liyan SHANG

Online First Date: 04 July 2022 Issue Date: 28 November 2022

Cite this article:

Shuwei ZHANG,Liyan SHANG,Zhen PAN, et al. Mechanism and control factors of hydrate plugging in multiphase liquid-rich pipeline flow systems: A review[J]. Front. Energy, 2022, 16(5): 747-773.

URL:

https://academic.hep.com.cn/fie/EN/10.1007/s11708-022-0830-z
https://academic.hep.com.cn/fie/EN/Y2022/V16/I5/747

Fig.1 Conceptual diagram of hydrate blockage in oil and gas pipelines (adapted with permission from Ref. [25]).

Fig.2 Schematic diagram of agglomeration and separation forces between hydrate particles (α is the contact angle and β is the semi-filled angle (adapted with permission from Ref. [24]).

Tab.1 Three major mechanisms of hydrate deposition

Fig.3 Schematic diagram of four processes of hydrate implantation and deposition (adapted with permission from Ref. [41]).

Fig.4 Schematic diagram of hydrate film growth in four systems (adapted with permission from Ref. [42]).

Fig.5 Schematic diagram of mechanism of hydrate particles adhesion to tube wall (adapted with permission from Ref. [43]).

Fig.6 Schematic diagram of mechanism of hydrates plugging in oil-based systems established by Turner et al. (adapted with permission from Ref. [45]).

Fig.7 Inward growth model of hydrate shell (adapted with permission from Ref. [46]).

Fig.8 Conceptual diagram of deposition process of hydrate on pipe wall (adapted with permission from Ref. [47]).

Fig.9 Force analysis diagram of adhesion of hydrate particles on pipe wall (adapted with permission from Ref. [43]).

Fig.10 Schematic diagram of hydrate blockage mechanism in pure water system (adapted with permission from Ref. [25]).

Fig.11 Conceptual mechanism diagram of oil-water demulsification (adapted with permission from Ref. [51]).

Fig.12 Oil-water demulsification image taken by PVM (adapted with permission from Ref. [51]).

Fig.13 Growth mechanism of hydrate film in a PD system proposed by Vijayamohan (adapted with permission from Ref. [54]).

Fig.14 Schematic diagram of migration of oil-water interface established by Akhfash et al. (adapted with permission from Ref. [55]).

Ref.	Time	Experimental device or method	Hydrate guest molecule type	Main research content	Research result
[63]	1995	High-pressure wheel loop	Methane, ethane, propane hydrate	Inhibition performance of chemical additives on gas hydrate	Most kinetic inhibitors can increase the degree of supercooling required for the formation of hydrates, thereby inhibiting the formation of hydrates
[64]	1999	NTNU (Norwegian University of Science and Technology) loop experiment	Methane or a mixture of methane, ethane, and propane	Flow characteristics of hydrate slurry under different hydrate concentrations	The apparent viscosity of the hydrate slurry increased with the increase of the hydrate concentration; in the turbulent state, the frictional pressure drop of the hydrate slurry was only determined by the nature of the water-carrying phase
[33]	2002	Archimede Loop	Methane hydrate	Influence of dispersant and kinetic inhibitor (PVP) on the formation and fluidity of methane hydrate slurry	The concentration of additives had a significant impact on the flow characteristics of water-in-oil emulsions and hydrate slurries, and additives can effectively alleviate pipe blockage
[65]	2012	ExxonMobil loop	He, N₂, CO₂, etc.	Main factors affecting the formation of hydrate slurry	Determination of the main parameters affected the transportation of hydrate slurry
[25]	2013	ExxonMobil loop	CH₄	Mechanism of hydrate formation and blocking in the high water content system	The mechanism was the increase of interaction and agglomeration between particles, which ultimately led to the formation of hydrate beds and wall deposits
[66]	2014	Small flow loop experiment	CH₄+C₃H₈/CH₄+i?C₄H₁₀ two-component gas hydrate	Effect of dual kinetic inhibition of PVP and L-Tyrosine on the induction period of binary component gas hydrate formation	The simultaneous addition of PVP and L-Tyrosine increased the induction time of gas hydrate formation several times, which was more effective than adding PVP alone as a kinetic inhibitor
[58]	2014	High-pressure hydrate experimental circuit	Natural gas hydrate	Influence of subcooling, supersaturation, flow rate, water content, and polymerization inhibitor concentration on the induction period of natural gas hydrate formation	Induction time was inversely proportional to the degree of subcooling; as flow rate and supersaturation increase, the induction time presented a V-shaped curve or gradually increased; the induction time decreased first and then increased with the increase of water content
[67]	2014	IFP-Lyre (Institut Francais Du Petrole) loop experiment	CH₄	Influence of factors such as moisture content, liquid phase flow rate, and polymerization inhibitors on the flow characteristics of hydrate slurry in the case of high water content	The higher the water content, the more difficult it was to crystallize the hydrate; addition of AA-LDHI (Anti-Agglomerates and Low Dosage Hydrate Inhibitor) could effectively maintain the fluidity of the pipeline
[68]	2014	University of Tulsa loop	Natural gas hydrate	Mechanism of hydrate formation and blocking in the PD system	The growth of hydrate/sediment on the tube wall seemed to be the dominant phenomenon of hydrate growth in PD systems
[69]	2017	CUPB (China University of Petroleum, Beijing) storage and transportation experimental loop	Natural gas hydrate	Mechanism of hydrate formation and blockage under different gas-liquid flow patterns	The blocking mechanism and pipe blocking tendency of hydrates were different under different flow patterns. (mentioned later)

Tab.2 Summary of the investigation of the loop experimental of hydrate

Fig.15 Variation of hydrate formation volume fraction, mixture flow rate, pressure drop, and temperature at different flow rates (adapted with permission from Ref. [35]).

Fig.16 Schematic diagram of effective volume fraction and water rate conversion in different flow rate systems (adapted with permission from Ref. [35]).

Fig.17 Variation in hydrate deposition rate and deposition thickness at different flow rates (adapted with permission from Ref. [48]).

Fig.18 Change of flow rate, relative pressure drop, slurry density, and the number of particles in the liquid phase in different flow patterns (adapted with permission from Ref. [78]).

Fig.19 Schematic diagram of hydrate blockage mechanism under different flow patterns (adapted with permission from Ref. [78]).

Fig.20 Behavior characteristics of hydrate slurry in specific flow patterns (adapted with permission from Ref. [78]).

Fig.21 Temperature-time curves at different water contents during formation of hydrates (adapted with permission from Ref. [18]).

Fig.22 (a) Hydrate induction time and (b) hydrate volume fraction at different water contents (adapted with permission from Ref. [18]).

Fig.23 Apparent viscosity and friction coefficient of hydrate under different water contents (adapted with permission from Ref. [18]).

Fig.24 Deposition rate and thickness of hydrate at different water contents (adapted with permission from Ref. [48]).

Fig.25 Formation of hydrates in pipeline during two types of blockage processes (adapted with permission from Ref. [49]).

Fig.26 Schematic diagrams of mechanisms of two types of blocking processes (adapted with permission from Ref. [49]).

1	B Gaurav, M N Goh, S E K Arumuganainar. et al.. Ultra-rapid uptake and the highly stable storage of methane as combustible ice. Energy and Environmental Science, 2020, 13( 12): 4946– 4961 https://doi.org/10.1039/D0EE02315A
2	S Song, B Shi, W Yu. et al.. Study on the optimization of hydrate management strategies in deepwater gas well testing operations. Journal of Energy Resources Technology, 2020, 142( 3): 033002
3	G Shi, S Song, B Shi. et al.. A new transient model for hydrate slurry flow in oil-dominated flowlines. Journal of Petroleum Science and Engineering, 2021, 196 : 108003 https://doi.org/10.1016/j.petrol.2020.108003
4	B Shi, S Song, Y Chen. et al.. Status of natural gas hydrate flow assurance research in China: a review. Energy and Fuels, 2021, 35( 5): 3611– 3658 https://doi.org/10.1021/acs.energyfuels.0c04209
5	S Song, B Shi, W Yu. et al.. A new methane hydrate decomposition model considering intrinsic kinetics and mass transfer. Chemical Engineering Journal, 2019, 361 : 1264– 1284 https://doi.org/10.1016/j.cej.2018.12.143
6	W Hao, J Wang, S Fan. et al.. Evaluation and analysis method for natural gas hydrate storage and transportation processes. Energy Conversion and Management, 2008, 49( 10): 2546– 2553 https://doi.org/10.1016/j.enconman.2008.05.016
7	H P Veluswamy, R Kumar, P Linga. Hydrogen storage in clathrate hydrates: current state of the art and future directions. Applied Energy, 2014, 122 : 112– 132 https://doi.org/10.1016/j.apenergy.2014.01.063
8	H Kubota, K Shimizu, Y Tanaka. et al.. Thermodynamic properties of R13 (CClF3), R23 (CHF3), R152a (C2H4F2), and propane hydrates for desalination of sea water. Journal of Chemical Engineering of Japan, 1984, 17( 4): 423– 429 https://doi.org/10.1252/jcej.17.423
9	M Yang, Y Song, L Jiang. et al.. Effects of operating mode and pressure on hydrate-based desalination and CO2 capture in porous media. Applied Energy, 2014, 135 : 504– 511 https://doi.org/10.1016/j.apenergy.2014.08.095
10	J Cai, C Xu, Z Xia. et al.. Hydrate-based methane separation from coal mine methane gas mixture by bubbling using the scale-up equipment. Applied Energy, 2017, 204 : 1526– 1534 https://doi.org/10.1016/j.apenergy.2017.05.010
11	D Zhong, K Ding, Y Lu. et al.. Methane recovery from coal mine gas using hydrate formation in water-in-oil emulsions. Applied Energy, 2016, 162 : 1619– 1626 https://doi.org/10.1016/j.apenergy.2014.11.010
12	N Xie, C Tan, S Yang. et al.. Conceptual design and analysis of a novel CO2 hydrate-based refrigeration system with cold energy storage. ACS Sustainable Chemistry and Engineering, 2019, 7( 1): 1502– 1511 https://doi.org/10.1021/acssuschemeng.8b05255
13	Z Liu, W Liu, C Lang. et al.. Viscosity investigation on metastable hydrate suspension in oil-dominated systems. Chemical Engineering Science, 2021, 238 : 116608 https://doi.org/10.1016/j.ces.2021.116608
14	X Li, C Xu, Z Chen. et al.. Tetra-n-butyl ammonium bromide semi-clathrate hydrate process for post-combustion capture of carbon dioxide in the presence of dodecyl trimethyl ammonium chloride. Energy, 2010, 35( 9): 3902– 3908 https://doi.org/10.1016/j.energy.2010.06.009
15	X Li, C Xu, Z Chen. et al.. Hydrate-based pre-combustion carbon dioxide capture process in the system with tetra-n-butyl ammonium bromide solution in the presence of cyclopentane. Energy, 2011, 36( 3): 1394– 1403 https://doi.org/10.1016/j.energy.2011.01.034
16	E G Hammerschmidt. Formation of gas hydrates in natural gas transmission lines. Industrial and Engineering Chemistry, 1934, 26( 8): 851– 855 https://doi.org/10.1021/ie50296a010
17	L A Stern, S Circone, S H Kirby. et al.. Temperature, pressure, and compositional effects on anomalous or “self” preservation of gas hydrates. Canadian Journal of Physics, 2003, 81( 1−2): 271– 283 https://doi.org/10.1139/p03-018
18	X Lv, J Zuo, Y Liu. et al.. Experimental study of growth kinetics of CO2 hydrates and multiphase flow properties of slurries in high pressure flow systems. RSC Advances, 2019, 9( 56): 32873– 32888 https://doi.org/10.1039/C9RA06445A
19	M Yang, Y Song, X Ruan. et al.. Characteristics of CO2 hydrate formation and dissociation in glass beads and silica gel. Energies, 2012, 5( 4): 925– 937 https://doi.org/10.3390/en5040925
20	H Zhang, J Du, Y Wang. et al.. Investigation into THF hydrate slurry flow behaviour and inhibition by an anti-agglomerant. RSC Advances, 2018, 8( 22): 11946– 11956 https://doi.org/10.1039/C8RA00857D
21	F Merlin, H Guitouni, H Mouhoubi. et al.. Adsorption and heterocoagulation of nonionic surfactants and latex particles on cement hydrates. Journal of Colloid and Interface Science, 2005, 281( 1): 1– 10 https://doi.org/10.1016/j.jcis.2004.08.042
22	Z M Aman, C A Koh. Interfacial phenomena in gas hydrate systems. Chemical Society Reviews, 2016, 45( 6): 1678– 1690 https://doi.org/10.1039/C5CS00791G
23	F Wang, P Chen, X Li. et al.. Effect of colloidal silica on the hydration behavior of calcium aluminate cement. Materials, 2018, 11( 10): 1849 https://doi.org/10.3390/ma11101849
24	S Song Z Liu L Zhou, et al.. Research progress on hydrate plugging in multiphase mixed rich-liquid transportation pipelines. Frontiers in Energy, 2020, online,
25	S V Joshi, G A Grasso, P G Lafond. et al.. Experimental flowloop investigations of gas hydrate formation in high water cut systems. Chemical Engineering Science, 2013, 97 : 198– 209 https://doi.org/10.1016/j.ces.2013.04.019
26	A Fidel-Dufour, F Gruy, J M Herri. Rheology of methane hydrate slurries during their crystallization in a water in dodecane emulsion under flowing. Chemical Engineering Science, 2006, 61( 2): 505– 515 https://doi.org/10.1016/j.ces.2005.07.001
27	M van der Hofstadt, R Fabregas, R Millan-Solsona. et al.. Internal hydration properties of single bacterial endospores probed by electrostatic force microscopy. ACS Nano, 2016, 10( 12): 11327– 11336 https://doi.org/10.1021/acsnano.6b06578
28	C J Taylor, L E Dieker, K T Miller. et al.. Micromechanical adhesion force measurements between tetrahydrofuran hydrate particles. Journal of Colloid and Interface Science, 2007, 306( 2): 255– 261 https://doi.org/10.1016/j.jcis.2006.10.078
29	S O Yang, D M Kleehammer, Z Huo. et al.. Temperature dependence of particle-particle adherence forces in ice and clathrate hydrates. Journal of Colloid and Interface Science, 2004, 277( 2): 335– 341 https://doi.org/10.1016/j.jcis.2004.04.049
30	F M Orr, L E Scriven, A P Rivas. Pendular rings between solids: meniscus properties and capillary force. Journal of Fluid Mechanics, 1975, 67( 4): 723– 742 https://doi.org/10.1017/S0022112075000572
31	C Liu, C Zhang, C Zhou. et al.. Effects of the solidification of capillary bridges on the interaction forces between hydrate particles. Energy and Fuels, 2020, 34( 4): 4525– 4533 https://doi.org/10.1021/acs.energyfuels.0c00463
32	Z M Aman, E P Brown, E D Sloan. et al.. Interfacial mechanisms governing cyclopentane clathrate hydrate adhesion/cohesion. Physical Chemistry Chemical Physics, 2011, 13( 44): 19796– 19806 https://doi.org/10.1039/c1cp21907c
33	T Palermo A Fidel-Dufour P Maurel, et al.. Model of hydrates agglomeration–application to hydrates formation in an acidic crude oil. In: 12th International Conference on Multiphase Production Technology, Barcelona, Spain, 2005
34	B Shi, L Ding, W Li. et al.. Investigation on hydrates blockage and restart process mechanisms of CO2 hydrate slurry flow. Asia-Pacific Journal of Chemical Engineering, 2018, 13( 3): e2193 https://doi.org/10.1002/apj.2193
35	Z Liu, M Vasheghani Farahani, M Yang. et al.. Hydrate slurry flow characteristics influenced by formation, agglomeration and deposition in a fully visual flow loop. Fuel, 2020, 277 : 118066 https://doi.org/10.1016/j.fuel.2020.118066
36	G Aspenes, L E Dieker, Z M Aman. et al.. Adhesion force between cyclopentane hydrates and solid surface materials. Journal of Colloid and Interface Science, 2010, 343( 2): 529– 536 https://doi.org/10.1016/j.jcis.2009.11.071
37	B V Balakin, A C Hoffmann, P Kosinski. et al.. Turbulent flow of hydrates in a pipeline of complex configuration. Chemical Engineering Science, 2010, 65( 17): 5007– 5017 https://doi.org/10.1016/j.ces.2010.06.005
38	O C Hernandez. Investigation of hydrate slurry flow in horizontal pipelines. Dissertation for the Doctoral Degree. Tulsa: The University of Tulsa, 2006
39	G H Kwak, K Lee, B R Lee. et al.. Quantification of the risk for hydrate formation during cool down in a dispersed oil-water system. Korean Journal of Chemical Engineering, 2017, 34( 7): 2043– 2048 https://doi.org/10.1007/s11814-017-0112-3
40	Z M Aman, W J Leith, G A Grasso. et al.. Adhesion force between cyclopentane hydrate and mineral surfaces. Langmuir: the ACS Journal of Surfaces and Colloids, 2013, 29( 50): 15551– 15557 https://doi.org/10.1021/la403489q
41	P Doron, M Simkhis, D Barnea. Flow of solid-liquid mixtures in inclined pipes. International Journal of Multiphase Flow, 1997, 23( 2): 313– 323 https://doi.org/10.1016/S0301-9322(97)80946-9
42	G Grasso. Investigation of hydrate formation and transportability in multiphase flow systems. Dissertation for the Doctoral Degree. Golden: Colorado School of Mines, 2015
43	S Hu, T H Kim, J G Park. et al.. Effect of different deposition mediums on the adhesion and removal of particles. Journal of the Electrochemical Society, 2010, 157( 6): H662 https://doi.org/10.1149/1.3377090
44	D J Turner. Clathrate hydrate formation in water-in-oil dispersions. Dissertation for the Doctoral Degree. Golden: Colorado School of Mines, 2005
45	D J Turner, K T Miller, E D Sloan. Methane hydrate formation and an inward growing shell model in water-in-oil dispersions. Chemical Engineering Science, 2009, 64( 18): 3996– 4004 https://doi.org/10.1016/j.ces.2009.05.051
46	C J Taylor, K T Miller, C A Koh. et al.. Macroscopic investigation of hydrate film growth at the hydrocarbon/water interface. Chemical Engineering Science, 2007, 62( 23): 6524– 6533 https://doi.org/10.1016/j.ces.2007.07.038
47	A K Sum, C A Koh, E D Sloan. Developing a comprehensive understanding and model of hydrate in multiphase flow: from laboratory measurements to field applications. Energy and Fuels, 2012, 26( 7): 4046– 4052 https://doi.org/10.1021/ef300191e
48	L Ding, B Shi, J Wang. et al.. Hydrate deposition on cold pipe walls in water-in-oil (W/O) emulsion systems. Energy and Fuels, 2017, 31( 9): 8865– 8876 https://doi.org/10.1021/acs.energyfuels.7b00559
49	G Song, Y Li, W Wang. et al.. Investigation of hydrate plugging in natural gas+diesel oil+water systems using a high-pressure flow loop. Chemical Engineering Science, 2017, 158 : 480– 489 https://doi.org/10.1016/j.ces.2016.10.045
50	M Akhfash, J A Boxall, Z M Aman. et al.. Hydrate formation and particle distributions in gas-water systems. Chemical Engineering Science, 2013, 104 : 177– 188 https://doi.org/10.1016/j.ces.2013.08.053
51	A A Majid, W Lee, V Srivastava. et al.. Experimental investigation of gas-hydrate formation and particle transportability in fully and partially dispersed multiphase-flow systems using a high-pressure flow loop. SPE Journal, 2018, 23( 3): 937– 951 https://doi.org/10.2118/187952-PA
52	D Sloan C Koh A K Sum, et al.. Natural Gas Hydrates in Flow Assurance. Burlington: Gulf Professional Publishing, 2010
53	A A Majid W Lee V Srivastava, et al.. The study of gas hydrate formation and particle transportability using a high pressure flowloop. In: Offshore Technology Conference, Houston, Texas, USA, 2016
54	P Vijayamohan. Experimental investigation of gas hydrate formation, plugging and transportability in partially dispersed and water continuous systems. Dissertation for the Doctoral Degree. Golden: Colorado School of Mines, 2015
55	M Akhfash, Z M Aman, S Y Ahn. et al.. Gas hydrate plug formation in partially-dispersed water-oil systems. Chemical Engineering Science, 2016, 140 : 337– 347 https://doi.org/10.1016/j.ces.2015.09.032
56	M Arjmandi B Tohidi A Danesh, et al.. Is subcooling the right driving force for testing low-dosage hydrate inhibitors? Chemical Engineering Science, 2005, 60( 5): 1313− 1321
57	A Vysniauskas, P R Bishnoi. A kinetic study of methane hydrate formation. Chemical Engineering Science, 1983, 38( 7): 1061– 1072 https://doi.org/10.1016/0009-2509(83)80027-X
58	X F Lv, B H Shi, Y Wang. et al.. Experimental study on hydrate induction time of gas-saturated water-in-oil emulsion using a high-pressure flow loop. Oil and Gas Science and Technology – Revue d'IFP Energies Nouvelles, 2015, 70( 6): 1111– 1124 https://doi.org/10.2516/ogst/2014032
59	Y Liu, B Shi, L Ding. et al.. Investigation of hydrate agglomeration and plugging mechanism in low-wax-content water-in-oil emulsion systems. Energy and Fuels, 2018, 32( 9): 8986– 9000 https://doi.org/10.1021/acs.energyfuels.8b01323
60	J L Peytavy, J P Monfort, C Gaillard. Investigation of methane hydrate formation in a recirculating flow loop: modeling of the kinetics and tests of efficiency of chemical additives on hydrate inhibition. Oil and Gas Science and Technology, 1999, 54( 3): 365– 374 https://doi.org/10.2516/ogst:1999033
61	X Lv, B Shi, Y Wang. et al.. Study on gas hydrate formation and hydrate slurry flow in a multiphase transportation system. Energy and Fuels, 2013, 27( 12): 7294– 7302 https://doi.org/10.1021/ef401648r
62	S Zhang, Z Pan, L Shang. et al.. Analysis of influencing factors on the kinetics characteristics of carbon dioxide hydrates in high pressure flow systems. Energy and Fuels, 2021, 35( 19): 16241– 16257 https://doi.org/10.1021/acs.energyfuels.1c02060
63	O Urdahl, A Lund, P Mørk. et al.. Inhibition of gas hydrate formation by means of chemical additives—I. Development of an experimental set-up for characterization of gas hydrate inhibitor efficiency with respect to flow properties and deposition. Chemical Engineering Science, 1995, 50( 5): 863– 870 https://doi.org/10.1016/0009-2509(94)00471-3
64	V Andersson, J S Gudmundsson. Flow properties of hydrate-in-water slurries. Annals of the New York Academy of Sciences, 2006, 912( 1): 322– 329 https://doi.org/10.1111/j.1749-6632.2000.tb06786.x
65	J W Lachance, L D Talley, D P Shatto. et al.. Formation of hydrate slurries in a once-through operation. Energy and Fuels, 2012, 26( 7): 4059– 4066 https://doi.org/10.1021/ef3002197
66	M R Talaghat. Experimental investigation of induction time for double gas hydrate formation in the simultaneous presence of the PVP and l-Tyrosine as kinetic inhibitors in a mini flow loop apparatus. Journal of Natural Gas Science and Engineering, 2014, 19 : 215– 220 https://doi.org/10.1016/j.jngse.2014.05.010
67	A Melchuna A Cameirão Y Ouabbas, et al.. Transport of hydrate slurry at high water cut. In: The 8 th International Conference on Gas Hydrates, Beijing, China, 2014
68	P Vijayamohan A Majid P Chaudhari, et al.. Hydrate modeling & flow loop experiments for water continuous & partially dispersed systems. In: Offshore Technology Conference, Houston, Texas, USA, 2014
69	L Ding, B Shi, X Lv. et al.. Hydrate formation and plugging mechanisms in different gas-liquid flow patterns. Industrial and Engineering Chemistry Research, 2017, 56( 14): 4173– 4184 https://doi.org/10.1021/acs.iecr.6b02717
70	Clain P, Delahaye A, Fournaison L, et al. Rheological properties of tetra- n-butylphosphonium bromide hydrate slurry flow. Chemical Engineering Journal, 2012, 193–194: 112−122
71	B Peng, J Chen, C Sun. et al.. Flow characteristics and morphology of hydrate slurry formed from (natural gas+diesel oil/condensate oil+water) system containing anti-agglomerant. Chemical Engineering Science, 2012, 84 : 333– 344 https://doi.org/10.1016/j.ces.2012.08.030
72	K Yan, C Sun, J Chen. et al.. Flow characteristics and rheological properties of natural gas hydrate slurry in the presence of anti-agglomerant in a flow loop apparatus. Chemical Engineering Science, 2014, 106 : 99– 108 https://doi.org/10.1016/j.ces.2013.11.015
73	B Shi, L Ding, Y Liu. et al.. Hydrate slurry flow property in W/O emulsion systems. RSC Advances, 2018, 8( 21): 11436– 11445 https://doi.org/10.1039/C7RA13495A
74	V Srivastava, M W Eaton, C A Koh. et al.. Quantitative framework for hydrate bedding and transient particle agglomeration. Industrial and Engineering Chemistry Research, 2020, 59( 27): 12580– 12589 https://doi.org/10.1021/acs.iecr.0c01763
75	W Liu, J Hu, X Li. et al.. Assessment of hydrate blockage risk in long-distance natural gas transmission pipelines. Journal of Natural Gas Science and Engineering, 2018, 60 : 256– 270 https://doi.org/10.1016/j.jngse.2018.10.022
76	I Rao, C A Koh, E D Sloan. et al.. Gas hydrate deposition on a cold surface in water-saturated gas systems. Industrial and Engineering Chemistry Research, 2013, 52( 18): 6262– 6269 https://doi.org/10.1021/ie400493a
77	M di Lorenzo, Z M Aman, K Kozielski. et al.. Underinhibited hydrate formation and transport investigated using a single-pass gas-dominant flowloop. Energy and Fuels, 2014, 28( 11): 7274– 7284 https://doi.org/10.1021/ef501609m
78	L Ding, B Shi, X Lv. et al.. Hydrate formation and plugging mechanisms in different gas-liquid flow patterns. Industrial & Engineering Chemistry Research, 2017, 56( 14): 4173– 4184 https://doi.org/10.1021/acs.iecr.6b02717
79	L Ding, B Shi, Y Liu. et al.. Rheology of natural gas hydrate slurry: effect of hydrate agglomeration and deposition. Fuel, 2019, 239 : 126– 137 https://doi.org/10.1016/j.fuel.2018.10.110
80	S R Davies, J A Boxali, C A Koh. et al.. Predicting hydrate-plug formation in a subsea tieback. SPE Production and Operations, 2009, 24( 4): 573– 578 https://doi.org/10.2118/115763-PA
81	K Kinnari, J Hundseid, X Li. et al.. Hydrate management in practice. Journal of Chemical and Engineering Data, 2015, 60( 2): 437– 446 https://doi.org/10.1021/je500783u
82	T B Charlton, M di Lorenzo, L E Zerpa. et al.. Simulating hydrate growth and transport behavior in gas-dominant flow. Energy and Fuels, 2018, 32( 2): 1012– 1023 https://doi.org/10.1021/acs.energyfuels.7b02199
83	H Moradpour, A Chapoy, B Tohidi. Bimodal model for predicting the emulsion-hydrate mixture viscosity in high water cut systems. Fuel, 2011, 90( 11): 3343– 3351 https://doi.org/10.1016/j.fuel.2011.06.038
84	X Liu, P B Flemings. Dynamic multiphase flow model of hydrate formation in marine sediments. Journal of Geophysical Research, 2007, 112( B3): B03101 https://doi.org/10.1029/2005JB004227
85	A R Oroskar, R M Turian. The critical velocity in pipeline flow of slurries. AIChE Journal, 1980, 26( 4): 550– 558 https://doi.org/10.1002/aic.690260405
86	J A Boxall, C A Koh, E D Sloan. et al.. Droplet size scaling of water-in-oil emulsions under turbulent flow. Langmuir: the ACS Journal of Surfaces and Colloids, 2012, 28( 1): 104– 110 https://doi.org/10.1021/la202293t
87	P G Saffman. The lift on a small sphere in a slow shear flow. Journal of Fluid Mechanics, 1965, 22( 2): 385– 400 https://doi.org/10.1017/S0022112065000824
88	A Richter, P A Nikrityuk. Drag forces and heat transfer coefficients for spherical, cuboidal and ellipsoidal particles in cross flow at sub-critical Reynolds numbers. International Journal of Heat and Mass Transfer, 2012, 55( 4): 1343– 1354 https://doi.org/10.1016/j.ijheatmasstransfer.2011.09.005
89	L E Zerpa, E D Sloan, C Koh. et al.. Hydrate risk assessment and restart-procedure optimization of an offshore well using a transient hydrate prediction model. Oil and Gas Facilities, 2012, 1( 5): 49– 56 https://doi.org/10.2118/160578-PA
90	W Wang, S Fan, D Liang. et al.. A model for estimating flow assurance of hydrate slurry in pipelines. Journal of Natural Gas Chemistry, 2010, 19( 4): 380– 384 https://doi.org/10.1016/S1003-9953(09)60094-3
91	P Chaudhari, L E Zerpa, A K Sum. A correlation to quantify hydrate plugging risk in oil and gas production pipelines based on hydrate transportability parameters. Journal of Natural Gas Science and Engineering, 2018, 58 : 152– 161 https://doi.org/10.1016/j.jngse.2018.08.008
92	Y Chen, J Gong, B Shi. et al.. Investigation into methane hydrate reformation in water-dominated bubbly flow. Fuel, 2020, 263 : 116691 https://doi.org/10.1016/j.fuel.2019.116691
93	G O Brown. The history of the darcy-weisbach equation for pipe flow resistance. In: American Society of Civil Engineers Environmental and Water Resources History Sessions at ASCE Civil Engineering Conference and Exposition 2002, Washington, D.C.. 2002, 34– 43
94	R Camargo, T Palermo, A Sinquin. et al.. Rheological characterization of hydrate suspensions in oil dominated systems. Annals of the New York Academy of Sciences, 2006, 912( 1): 906– 916 https://doi.org/10.1111/j.1749-6632.2000.tb06844.x
95	R Camargo T Palermo. Rheological properties of hydrate suspensions in an asphaltenic crude oil. In: Proceedings of the 4th International Conference on Gas Hydrates, Yokohama, Japan, 2002
96	D Eskin, B Scarlett. Model of the solids deposition in hydrotransport: an energy approach. Industrial and Engineering Chemistry Research, 2005, 44( 5): 1284– 1290 https://doi.org/10.1021/ie049453t
97	Y Wu, L Shang, Z Pan. et al.. Gas hydrate formation in the presence of mixed surfactants and alumina nanoparticles. Journal of Natural Gas Science and Engineering, 2021, 94 : 104049 https://doi.org/10.1016/j.jngse.2021.104049
98	S Zhang L Shang L Zhou, et al.. Hydrate deposition model and flow assurance technology in gas-dominant pipeline transportation systems: a review. Energy & Fuels, 2022, 36(4): 1747-1775
99	Y Qin, L Shang, Z Lv. et al.. Rapid formation of methane hydrate in environment-friendly leucine-based complex system. Energy, 2022, 254 : 124214 https://doi.org/10.1016/j.energy.2022.124214

[1]	Jibao ZHANG, Shujun CHEN, Ning MAO, Tianbiao HE. Progress and prospect of hydrate-based desalination technology[J]. Front. Energy, 2022, 16(3): 445-459.
[2]	Xin LYU, Qingping LI, Yang GE, Min OUYANG, Hexing LIU, Qiang FU, Junlong ZHU, Shouwei ZHOU. Analysis of physical properties of gas hydrate-bearing unconsolidated sediment samples from the ultra-deepwater area in the South China Sea[J]. Front. Energy, 2022, 16(3): 509-520.
[3]	Xin LYU, Qingping LI, Yang GE, Junlong ZHU, Shouwei ZHOU, Qiang FU. Fundamental characteristics of gas hydrate-bearing sediments in the Shenhu area, South China Sea[J]. Front. Energy, 2021, 15(2): 367-373.
[4]	Quan CAO, Dongyan XU, Huanfei XU, Shengjun LUO, Rongbo GUO. Efficient promotion of methane hydrate formation and elimination of foam generation using fluorinated surfactants[J]. Front. Energy, 2020, 14(3): 443-451.
[5]	Shouwei ZHOU, Qingping LI, Xin LV, Qiang FU, Junlong ZHU. Key issues in development of offshore natural gas hydrate[J]. Front. Energy, 2020, 14(3): 433-442.
[6]	Zhen PAN, Yi WU, Liyan SHANG, Li ZHOU, Zhien ZHANG. Progress in use of surfactant in nearly static conditions in natural gas hydrate formation[J]. Front. Energy, 2020, 14(3): 463-481.
[7]	R. LALITHA NARAYANA, V. RAMACHANDRA RAJU. Experimental study on performance of passive and active solar stills in Indian coastal climatic condition[J]. Front. Energy, 2020, 14(1): 105-113.
[8]	Foued CHABANE,Nesrine HATRAF,Noureddine MOUMMI. Experimental study of heat transfer coefficient with rectangular baffle fin of solar air heater[J]. Front. Energy, 2014, 8(2): 160-172.
[9]	Chunlong LIU, Qunyi ZHU, Zhengqi LI, Qiudong ZONG, Xiang ZHANG, Zhichao CHEN. Influence of different oil feed rate on bituminous coal ignition in a full-scale tiny-oil ignition burner[J]. Front Energ, 2013, 7(3): 406-412.
[10]	Lin ZUO, Lixia SUN, Changfu YOU. Latest progress in numerical simulations on multiphase flow and thermodynamics in production of natural gas from gas hydrate reservoir[J]. Front Energ Power Eng Chin, 2009, 3(2): 152-159.

Viewed

Full text

Abstract

Cited

Shared

Discussed