You are here
Home > BLOG > Flow Mechanics > An analytical equation for oil transport in nanopores of oil shale considering viscosity distribution

An analytical equation for oil transport in nanopores of oil shale considering viscosity distribution

Fig. 2 Structure of nanopores in organic material of shale formation. Reproduced with permission from (Zeng et al. 2017)

Acknowledgements

The authors wish to thank the National Basic Research Program of China (2015CB250900), the Program for New Century Excellent Talents in University (Grant No. NCET-13-1030), the National Natural Science Foundation of China (Grant No. 40974055), the National Science and Technology Major Projects of China (2016ZX05039 and 2016ZX05042), the National Natural fund of China (51490654), and the Science Foundation of China University of Petroleum, Beijing (No. C201605).

References

Akkutlu IY, Fathi E (2012) Multiscale gas transport in shales with local kerogen heterogeneities. SPE J 17:1002–1011

Alfarge D, Wei M, Bai B (2018) Data analysis for CO2-EOR in shale-oil reservoirs based on a laboratory database. J Petrol Sci Eng, 162:697–711

Ambrose RJ, Hartman RC, Diaz-campos M, Akkutlu IY, Sondergeld CH (2012) Shale gas-in-place calculations part I: new pore-scale considerations. SPE J 17:219–229

Bahrami M, Yovanovich MM, Culham JR (2006) Pressure drop of fully developed, laminar flow in rough microtubes. J Fluids Eng 128:632–637

Botan A, Rotenberg B, Marry V, Turq P, Noetinger B (2011) Hydrodynamics in clay nanopores. J Phys Chem C 115:16109–16115. https://doi.org/10.1021/jp204772c

Bousige C, Ghimbeu CM, Vix-Guterl C, Pomerantz AE, Suleimenova A, Vaughan G et al (2016) Realistic molecular model of kerogen’s nanostructure. Nat Mater 15:576–582. https://doi.org/10.1038/nmat4541

Chen X, Cao G, Han A, Punyamurtula VK, Liu L, Culligan PJ et al (2008) Nanoscale fluid transport: size and rate effects. Nano Lett 8:2988–2992. https://doi.org/10.1021/nl802046b

Cui JF, Sang Q, Li YJ, Yin CB, Li YC, Dong MZ (2017) Liquid permeability of organic nanopores in shale: Calculation and analysis. Fuel 202:426–434

Deng J, Zhu W, Ma Q (2014) A new seepage model for shale gas reservoir and productivity analysis of fractured well. Fuel 124:232–240. https://doi.org/10.1016/j.fuel.2014.02.001

Do DD, Do HD (2005) Adsorption of flexible n-alkane on graphitized thermal carbon black: analysis of adsorption isotherm by means of GCMC simulation. Chem Eng Sci 60:1977–1986. https://doi.org/10.1016/j.ces.2004.12.009

Falk K, Sedlmeier F, Joly L, Netz RR, Bocquet L (2010) Molecular origin of fast water transport in carbon nanotube membranes: superlubricity versus curvature dependent friction. Nano Lett 10:4067–4073. https://doi.org/10.1021/nl1021046

Falk K, Coasne B, Pellenq R, Ulm F, Bocquet L. Subcontinuum mass transport of condensed hydrocarbons in nanoporous media. Nat Commun 2015 https://doi.org/10.1038/ncomms7949

Feng D, Li XF, Wang XZ, Li J, Sun FR, Sun Z, Zhang T, Li PH, Chen Y, Zhang X (2018a) Water adsorption and its impact on the pore structure characteristics of shale clay. Appl Clay Sci 155:126–138

Feng D, Li XF, Wang XZ, Li J, Zhang X (2018b) Capillary filling under nanoconfinement: The relationship between effective viscosity and water-wall interactions. Int J Heat Mass Trans 118:900–910

Feng D, Li XF, Wang XZ, Li J, Zhang T, Sun Z, He MX, Liu Q, Qin JZ, Han S (2018c) Capillary filling of confined water in nanopores: Coupling the increased viscosity and slippage. Chem Eng Sci 186:228–239

Gruener S, Wallacher D, Greulich S, Busch M, Huber P (2016) Hydraulic transport across hydrophilic and hydrophobic nanopores: flow experiments with water and n-hexane. Phys Rev E 93:13102. https://doi.org/10.1103/PhysRevE.93.013102

Gu X, Mildner DFR, Cole DR, Rother G, Slingerland R, Brantley SL (2016) Quantification of organic porosity and water accessibility in Marcellus shale using neutron scattering. Energy Fuels 30:4438–4449. https://doi.org/10.1021/acs.energyfuels.5b02878

Guo L, Chen S, Robbins MO (2016) Slip boundary conditions over curved surfaces. Phys Rev E 93:13105. https://doi.org/10.1103/PhysRevE.93.013105

Harrison A, Cracknell RF, Krueger-Venus J, Sarkisov L (2014) Branched versus linear alkane adsorption in carbonaceous slit pores. Adsorption 20:427–437. https://doi.org/10.1007/s10450-013-9589-1

Ho AT, Papavassiliou DV, Lee LL, Striolo A (2011) Liquid water can slip on a hydrophilic surface. Proc Natl Acad Sci USA 108:16170–16175. https://doi.org/10.1073/pnas.1105189108

Ibrahimov RA, Bissada KKA (2010) Comparative analysis and geological significance of kerogen isolated using open-system (palynological) versus chemically and volumetrically conservative closed-system methods. Org Geochem 41:800–811. https://doi.org/10.1016/j.orggeochem.2010.05.006

Jia B, Tsau J-S, Barati B (2018) Role of molecular diffusion in heterogeneous, naturally fractured shale reservoirs during CO2 huff-n-puff. J Petrol Sci Eng 164:31–42

Joly L, Tocci G, Merabia S, Michaelides A (2016) Strong coupling between nanofluidic transport and interfacial chemistry: how defect reactivity controls liquid-solid friction through hydrogen bonding. J Phys Chem Lett 7:1381–1386. https://doi.org/10.1021/acs.jpclett.6b00280

Joseph S, Aluru NR (2008) Why are carbon nanotubes fast transporters of water? Nano Lett 8:452–458

Kannam SK, Todd BD, Hansen JS, Daivis PJ (2013) How fast does water flow in carbon nanotubes? J Chem Phys 138:94701. https://doi.org/10.1063/1.4793396

Kondori J, Zendehboudi S, Hossain ME (2017) A review on simulation of methane production from gas hydrate reservoirs: Molecular dynamics prospective. J Petrol Sci Eng 159:754–772

Kondratyuk P, Yates JT (2007) Molecular views of physical adsorption inside and outside of single-wall carbon nanotubes. Acc Chem Res 40:995–1004. https://doi.org/10.1021/ar700013c

Kou J, Lu H, Wu F, Fan J, Yao J (2014) Electricity resonance-induced fast transport of water through nanochannels. Nano Lett 14:4931–4936

Kou J, Yao J, Lu H, Zhang B, Li A, Sun Z et al (2015) Electromanipulating water flow in nanochannels. Angew Chem 127:2381–2385. https://doi.org/10.1002/ange.201408633

Lee R (2011) The outlook for population growth. Science 333:569–573CrossRefGoogle Scholar

Lee KP, Leese H, Mattia D (2012) Water flow enhancement in hydrophilic nanochannels. Nanoscale 4:2621–2627. https://doi.org/10.1039/b000000x

Li Y, Xu J, Li D (2010) Molecular dynamics simulation of nanoscale liquid flows. Microfluid Nanofluid 9:1011–1031. https://doi.org/10.1007/s10404-010-0612-5

Li J, Li K, Wu D, Feng T, Zhang Y, Zhang (2017) Thickness and stability of water film confined inside nanoslits and nanocapillaries of shale and clay. Int J Coal Geol 179:253–268

Lu S, Huang W, Chen F, Li J, Wang M, Xue H et al (2012) Classification and evaluation criteria of shale oil and gas resources: discussion and application. Pet Explor Dev 39:268–276. https://doi.org/10.1016/S1876-3804(12)60042-1

Majumder M, Chopra N, Andrews R, Hinds BJ (2005) Nanoscale hydrodynamics: enhanced flow in carbon nanotubes. Nature 438:44–44. https://doi.org/10.1038/43843a.

Majumder M, Chopra N, Hinds BJ (2011) Mass transport through carbon nanotube membranes in three different regimes: ionic diffusion and gas and liquid flow. ACS Nano 5:3867–3877

Mashl RJ, Joseph S, Aluru NR, Jakobsson E (2003) Anomalously immobilized water: a new water phase induced by confinement in nanotubes. Nano Lett 3:589–592. https://doi.org/10.1021/nl0340226

Mattia D, Calabro F (2012) Explaining high flow rate of water in carbon nanotubes via solid-liquid molecular interactions. Microfluid Nanofluid 13:125–130. https://doi.org/10.1007/s10404-012-0949-z

Mattia D, Leese H, Lee KP (2015) Carbon nanotube membranes: from flow enhancement to permeability. J Membr Sci 475:266–272. https://doi.org/10.1016/j.memsci.2014.10.035

McGonigal GC, Bernhardt RH, Thomson DJ (1990) Imaging alkane layers at the liquid/graphite interface with the scanning tunneling microscope. Appl Phys Lett 57:28–30. https://doi.org/10.1063/1.104234

Mosher K, He J, Liu Y, Rupp E, Wilcox J (2013) Molecular simulation of methane adsorption in micro- and mesoporous carbons with applications to coal and gas shale systems. Int J Coal Geol 109–110:36–44. https://doi.org/10.1016/j.coal.2013.01.001

Muscatello J, Jaeger F, Matar OK, Mu EA (2016) Optimizing water transport through graphene-based membranes: insights from nonequilibrium molecular dynamics. ACS Appl Mater Interfaces 8:12330–12336. https://doi.org/10.1021/acsami.5b12112

Myers TG (2011) Why are slip lengths so large in carbon nanotubes? Microfluid Nanofluid 10:1141–1145. https://doi.org/10.1007/s10404-010-0752-7

Neto C, Evans DR, Bonaccurso E, Butt H-J, Craig VSJ (2005) Boundary slip in Newtonian liquids: a review of experimental studies. Reports Prog Phys 68:2859–2897. https://doi.org/10.1088/0034-4885/68/12/R05

Pan C, Feng J, Tian Y, Yu L, Luo X, Sheng G et al (2005) Interaction of oil components and clay minerals in reservoir sandstones. Org Geochem 36:633–654. https://doi.org/10.1016/j.orggeochem.2004.10.013

Pang H, Pang XQ, Li D Xu Z (2018) Factors impacting on oil retention in lacustrine shale: Permian Lucaogou Formation in Jimusaer Depression, Junggar Basin. J Petrol Sci Eng 163:79–90

Park JH, Aluru NR (2007) Surface diffusion of n-alkanes: mechanism and anomalous behavior. Chem Phys Lett 447:310–315. https://doi.org/10.1016/j.cplett.2007.09.047

Park JH, Aluru NR (2010) Ordering-induced fast diffusion of nanoscale water film on graphene. J Phys Chem C 114:2595–2599. https://doi.org/10.1021/jp907512z

Qin X, Wang P, Sepehrnoori K, Pope GA (2000) Modeling asphaltene precipitation in reservoir simulation. Ind Eng Chem Res 39:2644–2654

Rafati R, Smith SR, Haddad AS, Novara R (2018) Effect of nanoparticles on the modifications of drilling fluids properties: a review of recent advances. J Petrol Sci Eng, 161:61–76

Ribas L, Herinque K (2017) José Manoel dos Reis Neto, Almério Barros França. Porto Alegre. The behavior of Irati oil shale before and after the pyrolysis process. J Petrol Sci Eng 152:156–164

Riewchotisakul S, Akkutlu IY (2016) Adsorption enhanced transport of hydrocarbon in organic nanopores. SPE J 21:28–30

Ritos K, Mattia D, Calabrò F, Reese JM (2014) Flow enhancement in nanotubes of different materials and lengths. J Chem Phys 140:14702. https://doi.org/10.1063/1.4846300

Sayed MA, Al-Muntasheri GA, Liang F (2017) Development of shale reservoirs: Knowledge gained from developments in North America. J Petrol Sci Eng 157:164–186

Schmatko T, Hervet H, Leger L (2005) Friction and slip at simple fluid-solid interfaces: the roles of the molecular shape and the solid-liquid interaction. Phys Rev Lett 94:244501. https://doi.org/10.1103/PhysRevLett.94.244501

Schwark L, Stoddart D, Keuser C, Spitthoff B, Leythaeuser D (1997) A novel sequential extraction system for whole core plug extraction in a solvent flow-through cell-Application to extraction of residual petroleum from an intact pore system in secondary migration studies. Org Geochem 26:19–31. https://doi.org/10.1016/S0146-6380(96)00163-5

Secchi E, Marbach S, Niguès A, Stein D, Siria A, Bocquet L (2016) Massive radiusdependent flow slippage in carbon nanotubes. Nature 537:210–213. https://doi.org/10.1038/nature19315

Severson BL, Snurr RQ (2007) Monte Carlo simulation of n-alkane adsorption isotherms in carbon slit pores. J Chem Phys 126:134708. https://doi.org/10.1063/1.2713097

Sha M, Zhang F, Wu G, Fang H, Wang C, Chen S et al (2008) Ordering layers of [bmim] [P F6] ionic liquid on graphite surfaces: molecular dynamics simulation. J Chem Phys 128:134504. https://doi.org/10.1063/1.2898497

Sheikholeslami M (2018a) Numerical simulation for solidification in a LHTESS by means of Nano-enhanced PCM. J Taiwan Inst Chem Eng 86:25–41

Sheikholeslami M (2018b) CuO-water nanofluid flow due to magnetic field inside a porous media considering Brownian motion. J Mol Liq 249:921–929

Sheikholeslami M (2018c) Numerical modeling of Nano enhanced PCM solidification in an enclosure with metallic fin. J Mol Liq 259:424–438

Sheng M, Li G, Sutula D, Tian S, Bordas SPA (2018) XFEM modeling of multistage hydraulic fracturing in anisotropic shale formations. J Petrol Sci Eng 162:801–812

Shovkun I, Espinoza DN (2018) Geomechanical implications of dissolution of mineralized natural fractures in shale formations. J Petrol Sci Eng 160:555–564

Soeder DJ (2018) The successful development of gas and oil resources from shales in North America. J Petrol Sci Eng 163:399–420

Song W, Yao J, Ma J et al (2018) Numerical simulation of multiphase flow in nanoporous organic matter with application to coal and gas shale systems. Water Res Res 54:1077–1092

Suleimenova A, Bake KD, Ozkan A, Valenza JJ, Kleinberg RL, Burnham AK et al (2014) Acid demineralization with critical point drying: a method for kerogen isolation that preserves microstructure. Fuel 135:492–497. https://doi.org/10.1016/j.fuel.2014.07.005

Sun FR, Yao YD, Li XF (2017a) Effect analysis of non-condensable gases on superheated steam flow in vertical single-tubing steam injection pipes based on the real gas equation of state and the transient heat transfer model in formation. J Petrol Explor Prod Technol. https://doi.org/10.1007/s13202-017-0419-y

Sun FR, Yao YD, Li XF (2017b) Effect of gaseous CO2 on superheated steam flow in wells. Eng Sci Technol Int J 20(6):1579–1585

Sun FR, Yao YD, Li XF (2017c) Numerical simulation of superheated steam flow in dual-tubing wells. J Petrol Explor Prod Technol. https://doi.org/10.1007/s13202-017-0390-7

Sun FR, Yao YD, Li XF, Li H, Chen G, Sun Z (2017d) A numerical study on the non-isothermal flow characteristics of superheated steam in ground pipelines and vertical wellbores. J Petrol Sci Eng 159:68–75

Sun FR, Yao YD, Li XF, Tian J, Zhu GJ, Chen Z (2017e) The flow and heat transfer characteristics of superheated steam in concentric dual-tubing wells. Int J Heat Mass Transf 115:1099–1108

Sun FR, Yao YD, Li XF, Yu PL, Ding GY, Zou M (2017f) The flow and heat transfer characteristics of superheated steam in offshore wells and analysis of superheated steam performance. Comput Chem Eng 100:80–93

Sun FR, Yao YD, Li XF, Zhao L (2017g) Type curve analysis of superheated steam flow in offshore horizontal wells. Int J Heat Mass Transf 113:850–860

Sun FR, Yao YD, Li XF, Yu PL, Zhao L, Zhang Y (2017h) A numerical approach for obtaining type curves of superheated multi-component thermal fluid flow in concentric dual-tubing wells. Int J Heat Mass Transf 111:41–53

Sun FR, Yao YD, Chen MQ, Li XF, Zhao L, Meng Y, Sun Z, Zhang T, Feng D (2017i) Performance analysis of superheated steam injection for heavy oil recovery and modeling of wellbore heat efficiency. Energy 125:795–804

Sun FR, Yao YD, Li XF, Zhao L, Ding GY, Zhang XJ (2017j) The mass and heat transfer characteristics of superheated steam coupled with non-condensing gases in perforated horizontal wellbores. J Petrol Sci Eng 156:460–467

Sun FR, Yao YD, Li GZ, Li XF, Chen MQ, Chen G, Zhang T (2018a) Analysis of superheated steam performance in offshore concentric dual-tubing wells. J Petrol Sci Eng 166:984–999

Sun FR, Yao YD, Li XF (2018b) The heat and mass transfer characteristics of superheated steam in horizontal wells with toepoint injection technique. J Petrol Explor Prod Technol https://doi.org/10.1007/s13202-017-0407-2

Sun FR, Yao YD, Li GZ, Li XF, Zhang T, Lu CG, Liu WY (2018c) An improved two-phase model for saturated steam flow in multi-point injection horizontal wells under steady-state injection condition. J Petrol Sci Eng 167:844–856

Sun FR, Yao YD, Li XF, Li GZ (2018d) A brief communication on the effect of seawater on water flow in offshore wells at supercritical state. J Petrol Explor Prod Technol https://doi.org/10.1007/s13202-018-0456-1

Sun FR, Yao YD, Li GZ, Li XF, Lu CG, Chen ZL (2018e) A model for predicting thermophysical properties of water at supercritical state in offshore CDTW. Measurement 124:241–251

Sun FR, Yao YD, Li XF, Li GZ, Han S, Liu Q, Liu WY (2018f) Type curve analysis of multi-phase flow of multi-component thermal fluid in toe-point injection horizontal wells considering phase change. J Petrol Sci Eng 165:557–566

Sun FR, Yao YD, Li XF, Li GZ, Miao YN, Han S, Chen ZL (2018g) Flow Simulation of the Mixture System of Supercritical CO2 & Superheated Steam in Toe-point Injection Horizontal wellbores. J Petrol Sci Eng 163:199–210

Sun FR, Yao YD, Li XF, Li GZ, Huang L, Liu H, Chen ZL, Liu Q, Liu WY, Cao M, Han S (2018h) Exploitation of heavy oil by supercritical CO2: effect analysis of supercritical CO2 on H2O at superheated state in integral joint tubing and annuli. Greenhouse Gases. https://doi.org/10.1002/ghg.1764

Sun FR, Yao YD, Li XF, Li GZ, Sun Z (2018i) A numerical model for predicting distributions of pressure and temperature of superheated steam in multi-point injection horizontal wells. Int J Heat Mass Transf 121:282–289

Sun FR, Yao YD, Li XF, Li GZ, Chen ZL, Chang YC, Cao M, Han S, Lv CH, Feng D, Sun Z (2018j) Effect of flowing seawater on supercritical CO2—superheated water mixture flow in an offshore oil well considering the distribution of heat generated by the work of friction. J Petrol Sci Eng 162:460–468

Sun FR, Yao YD, Li XF (2018k) The heat and mass transfer characteristics of superheated steam coupled with non-condensing gases in horizontal wells with multi-point injection technique. Energy 143:995–1005

Sun FR, Yao YD, Li XF, Li GZ, Liu Q, Han S, Zhou YJ (2018l) Effect of friction work on key parameters of steam at different state in toe-point injection horizontal wellbores. J Petrol Sci Eng 164:655–662

Thomas JA, Mcgaughey AJH (2008) Reassessing fast water transport through carbon nanotubes. Nano Lett 8:2788–2793. https://doi.org/10.1021/nl801361

Thomas JA, McGaughey AJH (2009) Water flow in carbon nanotubes: transition to subcontinuum transport. Phys Rev Lett 102:184502. https://doi.org/10.1103/PhysRevLett.102.184502

Thomas JA, McGaughey AJH, Kuter-Arnebeck O (2010) Pressure-driven water flow through carbon nanotubes: Insights from molecular dynamics simulation. Int J Therm Sci 49:281–289. https://doi.org/10.1016/j.ijthermalsci.2009.07.008

Walls JD, Sinclair SW (2011) Eagle Ford shale reservoir properties from digital rock physics. First Break 29(6):97–101

Wang S, Feng Q, Javadpour F, Xia T, Li Z (2015a) Oil adsorption in shale nanopores and its effect on recoverable oil-in-place. Int J Coal Geol 147–148:9–24. https://doi.org/10.1016/j.coal.2015.06.002

Wang S, Feng Q, Zha M, Lu S, Qin Y, Xia T et al (2015b) Molecular dynamics simulation of liquid alkane occurrence state in pores and slits of shale organic matter. Pet Explor Dev 42:844–851. https://doi.org/10.11698/PED.2015.06.10

Wang S, Javadpour F, Feng Q (2016a) Fast mass transport of oil and supercritical carbon dioxide through organic nanopores in shale. Fuel 181:741–758. https://doi.org/10.1016/j.fuel.2016.05.057

Wang S, Javadpour F, Feng Q (2016b) Molecular dynamics simulations of oil transport through inorganic nanopores in shale. Fuel 171:74–86. https://doi.org/10.1016/j.fuel.2015.12.071

Wang BY, Qin Y, Shen J, Zhang QS, Wang G (2018) Pore structure characteristics of low- and medium-rank coals and their differential adsorption and desorption effects. J Petrol Sci Eng 165:1–12

Wei MJ, Zhou J, Lu X, Zhu Y, Liu W, Lu L et al (2011) Diffusion of water molecules confined in slits of rutile TiO2(1 1 0) and graphite(0 0 0 1). Fluid Phase Equilib 302:316–320. https://doi.org/10.1016/j.fluid.2010.09.044

Wu K, Li X, Wang C, Yu W, Chen Z (2015) Model for surface diffusion of adsorbed gas in nanopores of shale gas reservoirs. Ind Eng Chem Res 54:3225–3236. https://doi.org/10.1021/ie504030v

Wu K, Chen Z, Li J, Li X, Xu J, Dong X (2017) Wettability effect on nanoconfined water flow. Proc Natl Acad Sci USA 114(13):3358–3363

Yang S, Liang M, Yu B, Zou M (2015a) Permeability model for fractal porous media with rough surfaces. Microfluid Nanofluid 18:1085–1093. https://doi.org/10.1007/s10404-014-1500-1

Yang T, Li X, Zhang D (2015b) Quantitative dynamic analysis of gas desorption contribution to production in shale gas reservoirs. J Unconv Oil Gas Resou 9:18–30. https://doi.org/10.1016/j.juogr.2014.11.003

Zeng Y, Ning ZF, Qi RR, Huang L (2017) LV C. Simulation of transport of shale gas through the nanopores of shales. Petrol Sci Bull 01:64–75. https://doi.org/10.3969/j.issn.2096-1693.2017.01.007

Zhang Q, Zheng J, Shevade A, Zhang L, Gehrke SH, Heffelfinger GS et al (2002) Transport diffusion of liquid water and methanol through membranes. J Chem Phys 117:808–818. https://doi.org/10.1063/1.1483297

Zhang T, Li XF, Li J, Feng D, Li PH, Zhang ZH, Chen Y, Wang S (2017a) Numerical investigation of the well shut-in and fracture uncertainty on fluid-loss and production performance in gas-shale reservoirs. J Nat Gas Sci Eng 46:421–435

Zhang T, Dong M, Li Y. A fractal permeability model for shale oil reservoir. Earth Environ Sci 108 (2017b) 032083

Zhu G, Yao J, Sun H, Zhang M, Xie M, Sun Z et al (2016) The numerical simulation of thermal recovery based on hydraulic fracture heating technology in shale gas reservoir. J Nat Gas Sci Eng 28:305–316. https://doi.org/10.1016/j.jngse.2015.11.051

Fengrui Sun [email protected]

Yuedong Yao [email protected]

Copyright information

© The Author(s) 2018

Open Access

This article is distributed under the terms of the Creative Commons Attribution 4.0 International License (http://creativecommons.org/licenses/by/4.0/), which permits unrestricted use, distribution, and reproduction in any medium, provided you give appropriate credit to the original author(s) and the source, provide a link to the Creative Commons license, and indicate if changes were made.

Emanuel Martin
Emanuel Martin is a Petroleum Engineer graduate from the Faculty of Engineering and a musician educate in the Arts Faculty at National University of Cuyo. In an independent way he’s researching about shale gas & tight oil and building this website to spread the scientist knowledge of the shale industry.
http://www.allaboutshale.com

One thought on “An analytical equation for oil transport in nanopores of oil shale considering viscosity distribution

Leave a Reply

13 + 9 =

Top