Effect of Clay Type on Emulsion Formation in Steam and Solvent Steamflooding

SPE Journal ◽  
2021 ◽  
pp. 1-11
Author(s):  
Taniya Kar ◽  
Berna Hascakir
Keyword(s):  
Oil Recovery ◽  
Reservoir Rock ◽  
Oil Sand ◽  
Oil Emulsion ◽  
Clay Particles ◽  
Hydrocarbon Solvents ◽  
Reservoir Type ◽  
Oil Water ◽  
Oil Components ◽  
Oil Emulsions

Summary The objectives of this study are to perform a fundamental analysis of the mutual interactions between crude oil components, water, hydrocarbon solvents, and clays, and to determine the optimum hydrocarbon solvent in solvent steamflooding for a particular reservoir type. The water/oil emulsion formation mechanism in the obtained oil for steam and solvent steamflooding processes has been studied via intermolecular associations between asphaltenes, water, and migrated clay particles. A series of 21 steam and solvent-steamflooding experiments has been conducted, first without any clays in the oil/sand packing, and then using two different clay types in the reservoir rock: Clay 1, which is kaolinite, and Clay 2, which is a mixture of kaolinite and illite. Paraffinic (propane, n-butane,n-pentane,n-hexane,n-heptane) and aromatic (toluene) solvents are coinjected with steam. Cumulative oil recovery is found to decrease in the following order: no clay, Clay 1, Clay 2. Based on the obtained produced oil analyses, Clay 1 and Clay 2 are found to have an affinity with the water and oil phases, respectively. Moreover, the biwettable nature of Clay 2 makes it dispersed in the oil phase toward the oil/water interface, stabilizing the water/oil emulsions. Paraffinic solvent n-hexane is found to be an optimum coinjector for solvent steamflooding in bitumen recovery.

Considerations for Using a Hydraulic Fracturing Fluid for Breaking Crude Oil Emulsion from Reservoir

2018 ◽  
Vol 69 (6) ◽  
pp. 1498-1500
Author(s):  
Lacramioara Olarasu ◽  
Maria Stoicescu ◽  
Ion Malureanu ◽  
Ion Onutu
Keyword(s):  
Hydraulic Fracturing ◽  
Crude Oil ◽  
Oil Production ◽  
Oil Field ◽  
Reservoir Rock ◽  
Oil Well ◽  
Strong Impact ◽  
Fracturing Fluid ◽  
Oil Emulsion ◽  
Oil Emulsions

In the oil industry, crude oil emulsions appear very frequently in almost all activities, starting with drilling and continuing with completion, production, transportation and processing. They are usually formed naturally or during oil production and their presence can have a strong impact on oil production and facilities. In this paper we addressed the problem of oil emulsions present in a reservoir with unfavorable flow properties. It is known that the presence of emulsions in a reservoir can influence both flow capacity and the quality of its crude oil, especially when they are associated with porous medium�s low values of permeability. Considering this, we have introduced a new procedure for selecting a special fluid of fracture. This fluid has two main roles: to create new flow paths from the reservoir rock to wells; to produce emulsion breaking of emulsified oil from pore of rocks. Best fracturing fluid performance was determined by laboratory tests. Selected fluid was then used to stimulate an oil well located on an oil field from Romania. In the final section of this paper,we are presenting a short analysis of the efficiency of the operation of hydraulic fracturing stimulation probe associated with the crude oil emulsion breaking process.

Influence of Emulsifiers on Physical Properties of Oil/Water Emulsions Containing Ostrich Oil

2018 ◽  
Vol 777 ◽  
pp. 592-596
Author(s):  
Juthaporn Ponphaiboon ◽  
Sontaya Limmatvapirat ◽  
Chutima Limmatvapirat
Keyword(s):  
Zeta Potential ◽  
Physical Properties ◽  
Droplet Size ◽  
Emulsion Stability ◽  
Tween 80 ◽  
High Viscosity ◽  
Soy Lecithin ◽  
Oil Emulsion ◽  
Oil Water ◽  
Oil Emulsions

The fabrication of oil/water (O/W) emulsions in order to prepare the spray-dried encapsulated bioactive ostrich oil emulsions can be useful for increasing stability of commercial products. In this study, O/W emulsions were stabilized with mixed emulsifiers (Span and Tween) or soy lecithin. The effects of emulsifiers on the physical properties of emulsions containing ostrich oil were investigated. Results showed that the addition of a mixture of Span and Tween emulsifiers at concentrations between 5 and 15% w/w reduced the droplet size of the emulsions but did not decrease the zeta potential in the emulsion system. The smallest droplet size of 5.01±0.43 μm was obtained from the emulsion containing 15% w/w mixture of Span 20 and Tween 80. The zeta potential values of all emulsions containing a mixture of Span and Tween emulsifiers in the concentration range of 5 to 20% w/w were between-23 and-55 mV. In addition, the viscosity of these emulsions increased with increases in the concentrations of both emulsifiers. The stable 20% w/w ostrich oil emulsion stabilized with 15% w/w Span 20/Tween 80 presented viscosity equal to 69.56±1.82 cP. For 10% w/w ostrich oil emulsions stabilized with lecithin, the droplet size and zeta potential of the emulsions tended to decrease with increasing lecithin concentrations. An emulsion containing 10% w/w lecithin exhibited the smallest droplet size (3.93±0.11 μm). The zeta potential values of all emulsions composed of 1-15% w/w lecithin were between-33 and –66 mV and the viscosity of these emulsions increased with increases in the concentrations of lecithin. The stable 10% w/w ostrich oil emulsion stabilized with 10% w/w lecithin exhibited a high viscosity of 172.50±1.01cP. In summary, 10% w/w lecithin provides better emulsion stability than 15% w/w Span 20/Tween 80. These results therefore reveal important parameters for the fabrication of stable O/W emulsions containing ostrich oil.

scholarly journals Surfactant (UMP) for emulsification and stabilization of water-in-crude oil emulsions (W/O)

2020 ◽  
Vol 2 (2) ◽  
pp. 18-21
Author(s):  
N. H. Abdurahman ◽  
H. A. Magdib
Keyword(s):  
Crude Oil ◽  
Oil Refinery ◽  
Oil Emulsion ◽  
Optimum Formulation ◽  
Emulsion Stabilization ◽  
Oil Water ◽  
Oil Emulsions ◽  
The Stability ◽  
Water In Oil Emulsion ◽  
Petroleum Oil

The purpose of this research is to look into the formulation and evaluation of concentrated water-in-oil (W/O) emulsions stabilized by UMP NS-19-02 surfactant and their application for crude oil emulsion stabilization using gummy Malaysian crude oil. A two-petroleum oil from Malaysia oil refinery, i.e., Tapis petroleum oil and Tapis- Mesilla blend, were utilized to make water-in-oil emulsions. The various factors influencing emulsion characteristics and stability were evaluated. It was discovered that the stability of the water-in-oil emulsion improved by UMP NS-19-02 improved as the surfactant content rises, resulting in the decline of the crude oil-water interfacial tension (IFT). Nevertheless, the most optimum formulation of W/O emulsion was a 50:50 W/O ratio with 1.0% surfactant. Additionally, raising the oil content, salt concentration, duration and mixing speed, and pH of the emulsion resulted in higher emulsion stability. It also raised the temperature of the initial mixing, which significantly decreased the formulated emulsions' viscosity. The results showed that stable emulsions could be formed using the UMP NS-19-02 surfactant.

Application of ZnO Nanostructures in Improvement of Effective Surface Parameters in EOR Process

2013 ◽  
Vol 26 ◽  
pp. 9-16 ◽  
Author(s):  
Pouriya Esmaeilzadeh ◽  
Zahra Fakhroueian ◽  
Mohammad Nadafpour ◽  
Alireza Bahramian
Keyword(s):  
Surface Tension ◽  
Oil Recovery ◽  
Recovery Process ◽  
Contact Angles ◽  
Carbonate Reservoir ◽  
Reservoir Rock ◽  
Potential Applications ◽  
Wet Condition ◽  
Oil Water ◽  
Zno Nanofluids

ZnO nanosphericals and nanorods have interesting potential applications in various fields such as antibacterial and enhanced oil recovery process. In this work, it was shown that 30 ml of a water-based solution containing 3% of ZnO nanofluids could significantly change the wettability of a carbonate reservoir rock from a strongly oil-wet alter to a strongly water-wet condition, after 3 days aging of the rock at 70°C in the designed solution. Moreover, we have studied air-water and oil-water interfacial tensions of system containing nanofluids. Fluids included ZnO nanoparticles and quantum dots nanostructures (QDOTs ZnO) could effectively decrease the n-decane/water interfacial tension and air/water surface tension. So their efficiency is much higher in comparison with distilled water.The stabilization of various aqueous ZnO nanostructured in mixtures of NaCl, CaCl2, MgCl2and Na2SO4salts were investigated, and 50000-163000 ppm transparent and stable nanosalt fluids were fabricated. Wettability of an oil-wet carbonate rock aged for 3 days at 70°C in the designed ZnO nanosalt fluids was studied by measuring the contact angles. The results show a strong change in wettability of carbonate rocks from oil-wet to more water-wet condition. These nanosalt fluids performed an excellent trend of surface tension and IFT reduction in comparison with distilled water too.

scholarly journals Interfacial and Colloidal Forces Governing Oil Droplet Displacement: Implications for Enhanced Oil Recovery

2018 ◽  
Vol 2 (3) ◽  
pp. 30 ◽  
Author(s):  
Suparit Tangparitkul ◽  
Thibaut Charpentier ◽  
Diego Pradilla ◽  
David Harbottle
Keyword(s):  
Contact Angle ◽  
Enhanced Oil Recovery ◽  
Solid Surface ◽  
Oil Recovery ◽  
Reservoir Rock ◽  
Equilibrium Contact Angle ◽  
Oil Droplet ◽  
Oil Film ◽  
Colloidal Forces ◽  
Oil Water

Growing oil demand and the gradual depletion of conventional oil reserves by primary extraction has highlighted the need for enhanced oil recovery techniques to increase the potential of existing reservoirs and facilitate the recovery of more complex unconventional oils. This paper describes the interfacial and colloidal forces governing oil film displacement from solid surfaces. Direct contact of oil with the reservoir rock transforms the solid surface from a water-wet to neutrally-wet and oil-wet as a result of the deposition of polar components of the crude oil, with lower oil recovery from oil-wet reservoirs. To enhance oil recovery, chemicals can be added to the injection water to modify the oil-water interfacial tension and solid-oil-water three-phase contact angle. In the presence of certain surfactants and nanoparticles, a ruptured oil film will dewet to a new equilibrium contact angle, reducing the work of adhesion to detach an oil droplet from the solid surface. Dynamics of contact-line displacement are considered and the effect of surface active agents on enhancing oil displacement discussed. The paper is intended to provide an overview of the interfacial and colloidal forces controlling the process of oil film displacement and droplet detachment for enhanced oil recovery. A comprehensive summary of chemicals tested is provided.

Displacement of Polymers in Waterflooded Porous Media and Its Effects on a Subsequent Micellar Flood

1977 ◽  
Vol 17 (05) ◽  
pp. 358-368 ◽  
Author(s):  
Mahmoud K. Dabbous
Keyword(s):  
Porous Medium ◽  
Porous Media ◽  
Oil Recovery ◽  
Phase Distribution ◽  
Mobility Control ◽  
Reservoir Rock ◽  
Residual Oil ◽  
Improved Oil Recovery ◽  
Residual Resistance ◽  
Oil Water

Abstract Injection of polymers in advance of a micellar fluid slug has been considered to improve reservoir volumetric sweep in a tertiary-mode micellar flood. An investigation was made of the injection of polyacrylamide-type polymers in waterflooded polyacrylamide-type polymers in waterflooded porous media and its effects on a subsequent porous media and its effects on a subsequent micellar flood. It was found that the presence of waterflood residual oil saturations in the porous medium increased the flow resistance and residual resistance factors (2- to 3.5-fold) compared with their corresponding values when the rock was free of residual oil. Inaccessible pore volume to polymer flow also appeared to be larger when waterflood residual oil saturations were present. These effects have been attributed to wettability and phase distribution of fluids in the porous medium. phase distribution of fluids in the porous medium. The study emphasized basic differences in the flow behavior of polymer injected ahead of a micellar slug (to improve sweep) and behind the micellar fluid (to control mobility). Both effects are for improved oil-recovery efficiency. Water mobility was greatly reduced following the displacement of polyacrylamide polymers in the waterflooded cores, yet mobility of the oil-water bank in a subsequent micellar flood was reduced to a lesser degree than the water bank. For a residual resistance factor to water ranging from 2 to 7, mobility control of a subsequent micellar flood could be achieved with a 22- to 39-percent increase in polymer concentration in the mobility buffer bank. This increase is in excess of the concentration required for a flood not preceded with polymer injection. Polymer preinjection had no adverse effects on oil displacement characteristics of the micellar fluid and appeared to reduce surfactant adsorption on the rock for the polymer-micellar system studied. Some experimental data indicated that the oil bank breaks through earlier and at a slightly higher oil cut in linear core floods. Such a result is theoretically feasible if the reduced-mobility water is not completely displaced at the front end (immiscible portion) of the oil-water bank. Oil-bank breakthrough probably would be delayed in the reservoir because of the action of the preinjected polymer to decrease the flow of fluids in polymer to decrease the flow of fluids in high-permeability zones. Introduction In a previous paper, preinjection of polymers in advance of a micellar slug was proposed as a means for improving reservoir volumetric sweep and oil recovery by a micellar flood. Increased flooding efficiency should result from reduced interwell permeability contrast in the reservoir following the polymer treatment. Preinjection of polymers also should result in better preflushing polymers also should result in better preflushing efficiency in displacing incompatible formation brines over "conventional" water preflushes. Thus, an improved oil-recovery method designed to increase reservoir volumetric sweep and miscibly recover tertiary oil consists ofpreinjection of a carefully designed slug of preinjection of a carefully designed slug of high-molecular-weight polyacrylamide polymers followed by a water-bank spacer to displace the polymer in the interwell area, andinjection of polymer in the interwell area, andinjection of a surfactant (micellar) slug followed by a polymer mobility buffer bank and chase water. The fluid banks that are injected or developed during the process are illustrated in Fig. 1. Mixing and process are illustrated in Fig. 1. Mixing and interaction zones at fluid-bank boundaries are not shown in the schematic. The preinjection of a polymer is intended to rectify interwell permeability variation. The polymer is injected in reservoir rock that has waterflood residual oil saturations. SPEJ p. 358

Adsorption Of Nonionic Surfactants On Clay Minerals

2012 ◽  
Author(s):  
Radzuan Junin ◽  
Tahmineh Amirian ◽  
Ahmad Kamal Idris
Keyword(s):  
Clay Minerals ◽  
Clay Mineral ◽  
Oil Recovery ◽  
Nonionic Surfactants ◽  
Mineralogical Composition ◽  
Reservoir Rock ◽  
Chemical Solution ◽  
Reservoir Rocks ◽  
Oil Water ◽  
Rock Minerals

The adsorption of surfactants from aqueous solutions in porous media is very significant in the enhanced oil recovery (EOR) of oil reservoirs. Surfactant loss due to adsorption on the reservoir rocks weakens the efficiency of the chemical solution injected to decrease the oil–water interfacial tension (IFT). This study investigated the effect of the mineralogical composition of adsorbents on adsorption. Nonionic surfactants were injected into sand packs in which different amounts of clay minerals (kaolinite and illite) were added and compacted in a sand pack holder. The amount of surfactant adsorbed was quantified by subtracting the concentration of surfactants after adsorption from the initial concentration. It was concluded that there is a relationship between the adsorption of nonionic surfactants and the amount of clay mineral in the adsorbents because the quantity of surfactant adsorbed by adsorbents increased when the percentage of clay mineral in the adsorbents increased (from 2 to 8% in the sand packs). The clay mineral illite has a stronger adsorption power for nonionic surfactants than does kaolinite. Key words: Adsorption, reservoir rock minerals, clay minerals, nonionic surfactants

Application of the Marangoni Effect in Nanoemulsion on Improving Waterflooding Technology for Heavy-Oil Reservoirs

SPE Journal ◽  
2017 ◽  
Vol 23 (03) ◽  
pp. 831-840 ◽  
Author(s):  
Danian Zhang ◽  
Xuan Du ◽  
Xinmin Song ◽  
Hongzhuang Wang ◽  
Xiuluan Li ◽  
...  
Keyword(s):  
Shear Stress ◽  
Kinetic Energy ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Marangoni Effect ◽  
Production Method ◽  
Heavy Oil Recovery ◽  
Oil Sand ◽  
Water Emulsion ◽  
Oil Water

Summary Waterflooding is considered an important cold-production method because it is economically advantageous for heavy-oil-reservoir development; however, its efficiency is not remarkable because of the adverse oil/water-mobility ratio and cold damage from solid-state adsorption. To address this problem, oil/water emulsion is critical for improving the recovery by significantly altering oil mobility. Previous research is mainly focused on the effect of surfactants, salinity, and water/oil ratio on emulsion formation, rather than on the effect of kinetic energy under low or no shear stress on emulsification. In this study, experiments are conducted using a microscope to observe oil/water interfacial turbulence (Marangoni effect) when oil is dropped into a nanoemulsion. The purpose of this study is to form an emulsion using the interfacial turbulence under low or no shear stress, to improve heavy-oil recovery under waterflooding. The interfacial movement between a nanoemulsion and oil and the mechanism of formation of the emulsion are investigated. The Marangoni effect and mass transfer are observed by use of a microscope and low field nuclear magnetic resonance (NMR), respectively. Nanoemulsion, along with other methods of chemical enhanced oil recovery (EOR), is compared by conducting coreflooding and sandpack-flooding experiments after waterflooding. The results show that the Marangoni effect can help to emulsify and remove the oil from oil sand by converting interfacial energy into kinetic energy. On the basis of flooding-experiment results, we conclude that slug injection with a combination of nanoemulsion flooding and polymer flooding is an effective method for improving heavy-oil recovery.

Destruction of water-in-oil emulsions in electromagnetic fields in a dynamic mode

2012 ◽  
Vol 9 (1) ◽  
pp. 110-115
Author(s):  
L.A. Kovaleva ◽  
R.R. Zinnatullin ◽  
V.N. Blagochinnov ◽  
A.A. Musin ◽  
Yu.I. Fatkhullina ◽  
...  
Keyword(s):  
Dielectric Properties ◽  
Radio Frequency ◽  
Electromagnetic Fields ◽  
Dynamic Mode ◽  
Droplet Dynamics ◽  
Oil Emulsion ◽  
Numerical Studies ◽  
Em Field ◽  
Oil Emulsions ◽  
Water In Oil Emulsion

Some results of experimental and numerical studies of the influence of radio-frequency (RF) and microwave (MW) electromagnetic (EM) fields on water-in-oil emulsions are presented. A detailed investigation of the dependence of the dielectric properties of emulsions on the frequency of the field makes it possible to establish the most effective frequency range of the EM influence. The results of water-in-oil emulsion stability in the RF EM field depending on their dielectric properties are presented. The effect of the MW EM field on the emulsion in a dynamic mode has been studied experimentally. In an attempt to understand the mechanism of emulsion destruction the mathematical model for a single emulsion droplet dynamics in radio-frequency (RF) and microwave (MW) electromagnetic fields is formulated.

Demulsification of a Water-in-crude Oil Emulsion with a Corn Oil BasedDemulsifier using the Response Surface Methodology: Modelling and Optimization

2021 ◽  
Vol 14 ◽  
Author(s):  
Abed Saad ◽  
Nour Abdurahman ◽  
Rosli Mohd Yunus
Keyword(s):  
Response Surface Methodology ◽  
Crude Oil ◽  
Water Content ◽  
Response Surface ◽  
Separation Efficiency ◽  
Corn Oil ◽  
Oil Emulsion ◽  
Optimal Values ◽  
Input Variables ◽  
Oil Emulsions

: In this study, the Sany-glass test was used to evaluate the performance of a new surfactant prepared from corn oil as a demulsifier for crude oil emulsions. Central composite design (CCD), based on the response surface methodology (RSM), was used to investigate the effect of four variables, including demulsifier dosage, water content, temperature, and pH, on the efficiency of water removal from the emulsion. As well, analysis of variance was applied to examine the precision of the CCD mathematical model. The results indicate that demulsifier dose and emulsion pH are two significant parameters determining demulsification. The maximum separation efficiency of 96% was attained at an alkaline pH and with 3500 ppm demulsifier. According to the RSM analysis, the optimal values for the input variables are 40% water content, 3500 ppm demulsifier, 60 °C, and pH 8.

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