Available online at http://ijcpe.uobaghdad.edu.iq and www.iasj.net Iraqi Journal of Chemical and Petroleum Engineering Vol.22 No.1 (March 2021) 29 – 38 EISSN: 2618-0707, PISSN: 1997-4884 Corresponding Authors: Name : Ayat Ragheb Muhammad Al-Karbalai, Email: ayaatragheb3@gmail.com , Name: Adel Sharif Hammadi, Email: 80013@uotechnology.edu.iq, Name: Ghassan Hamid Abdul Majeed, Email: ghmajeed@gmail.com IJCPE is licensed under a Creative Commons Attribution-NonCommercial 4.0 International License. Treating Wet Oil in Amara Oil Field Using Nanomaterial (SiO2) With Different Types of De emulsifiers Ayat Ragheb Muhammad Al-Karbalai a , Adel Sharif Hammadi b and Ghassan Hamid Abdul Majeed c a Department of Petroleum Technology / College of Engineering / University of Technology, b Department of Chemical Engineering / College of Engineering / University of Technology, c Research and Development Department / Ministry of Higher Education and Scientific Research / Baghdad, Abstract One of the most important problems in the oil production process and when its continuous flow, is emulsified oil (w/o emulsion), which in turn causes many problems, from the production line to the extended pipelines that are then transported to the oil refining process. It was observed that the nanomaterial (SiO2) supported the separation process by adding it to the emulsion sample and showed a high separation rate with the demulsifiers (RB6000) and (sebamax) where the percentage of separation was greater than (90 and 80 )% respectively, and less than that when dealing with (Sodium dodecyl sulfate and Diethylene glycol), the percentage of separation was (60% and 50%) respectively. The high proportion of (NaCl + distilled water) raises the probability of the separation efficiency as the separation was (88.5,79)% and (65.5, 55) % for (RB6000, SebaMax)respectively with (SiO2) at 70 °C, while the results of separation were (77,85)% and (65,40) for (RB6000, Seba Max) respectively with (SiO2) at 50 °C after 120 minutes, where the (w/o ratio) was (9:1) for the high separation results and (7:3) for the lower separation results, at a speed of (12000rpm), and with a salt concentration of (1500) ppm, and less of these results at lower volumetric and temporal conditions. The (NaCl) salt deals with the wall films separating the droplets and reduces their viscosity [1]. As for the pH factor, it is at the value (2 and 3) represent a stable emulsion that is difficult to separate easily, but with the passage of raising the pH away from the acidic medium and near to the basic direction, a significant increase in the separation process was observed compared with the acidic medium at lower values, after 120 minutes the separation seemed to be good efficient, reaching (60 and 70) % respectively, while at the same time the emulsion reached a more efficient separation level with a pH of ( 8 and 7) equal to (80 and 87.3) %, at 50 °C with SebaMax demulsifier in presence of (SiO2), and with the same pH values, an increase was observed in the separation with the increase in temperature to (70 °C), then it returns to be a reverse emulsifier when the value exceeds (10) to (11, 12, 13). Keywords: emulsion, demulsifiers, crude oil, saltwater, w/o emulsion, nanomaterial Received on 18/08/2020, Accepted on 12/12/2020, published on 30/03/2021 https://doi.org/10.31699/IJCPE.2021.1.4 1- Introduction In the oil production process, the formation of emulsions such as water in oil (W / O) is common due to the simultaneous continuous flow of the produced oil and water and high shear rates [2], which are mainly associated with the throttle valves, which leads to an increase in the area of the oil and water phases. In this case, inorganic colloids are accompanied by organic molecules and molecules with active interfaces (for example, asphalt and naphthenic acids) that increase the viscosity of the emulsion mechanically, resulting in a stable emulsion. This stability leads to a noticeable increase in the viscosity of the emulsion formed that can become greater than that of the oil itself, which leads to loss of system head, and thus reduces the productivity of wells and the capacity of the production system, mainly in deep waters, with a significant increase in production costs[3]. Some Iraqi oil fields, especially the Amara field in Maysan Governorate (about 10 km southwest of the city of Amara), suffer from the problem of wet oil (emulsion) [4]. The presence of this contamination in the oil is a big problem that leads to reducing the efficiency of the units that the oil passes through production processes [5]. The presence of salts will lead to precipitation in the heat exchanger tubes and furnaces in the form of solid blocks that reduce the diameters of these tubes and then increase the skin temperature and cause damage with them, and therefore these units are completely damaged, which leads to a large loss in production due to the suspension of these units from intentional maintenance [6]. http://ijcpe.uobaghdad.edu.iq/ http://www.iasj.net/ mailto:ayaatragheb3@gmail.com mailto:80013@uotechnology.edu.iq mailto:ghmajeed@gmail.com http://creativecommons.org/licenses/by-nc/4.0/ https://doi.org/10.31699/IJCPE.2021.1.4 A. R. M. Al-Karbalai et al. / Iraqi Journal of Chemical and Petroleum Engineering 22,1 (2021) 29 - 38 30 As a result of the presence of water in the oil and its containment of a large number of salts that are mainly available in the form of chlorides (CaCl2), (MgCl), and (NaCl), hydrochloric acid is formed as a result of the dissolution of calcium chloride during the distillation process, and this acid has a great corrosive effect, which causes Corrosion of units and equipment. [7]. Emulsions also cause an increase in energy consumption because the presence of water in the crude oil leads to an increase in energy consumption[8], all of these problems reduce the economic oil factor in the Iraqi market and the factor of the low quality of these heavy oils, according to (A. Saniere et al.,2004), options include improving quality to produce marketable crude oil, including carbon subtraction processes such as carbonization or hydrogen addition processes, the dilution process is one of the methods for improving heavy oils and the least costly, as higher quality oil is used to produce a product that can be further improved in another way[9]. The results showed that the (nano-SiO2) should interact with asphalt and resin surfaces and reduce the stability of the membranes surrounding the emulsion droplets as the addition of nanomaterial accelerates the process of breaking the inner interfacial film and isolates water droplets faster and in the shortest time possible [10]. While (D.M. Pinchao, and et al) found that the optimum separation efficiency (92%) was achieved at a concentration of 1000 ppm SiO2 nanoparticles and (5:5 ratio), an increase of 15% compared to the amount of water separated using only the de-emulsifying agent. On the other hand, the concentrations of 4000ppm and 10,000ppm of SiO2 nanoparticles reached much lower amounts than the water separation, 4%, respectively, due to the over-saturation in the mixture. [11]. In this research, water surfactants (that can be mixed with water) will be dealt with to tear the water droplet membrane and sediment it away from the oil drop, solid nanomaterials (powder) will be used where the action of the solid particles is to break the elastic membranes and thus drops coalesce with some of them and separated from the oil. 2- Experimental Work 2.1. Work method The method of work that was relied upon is (bottle testing), which includes adding crude oil samples after mixing it with a homogeneous mixer device for a period of (6 minutes) to a group of glass cylinders containing gradients per volume unit (milliliter) after which the demulsifier is added and the bottle shaken for (3 Minutes) and then these samples are placed in a water bath with different temperatures (15, 50, 70, 100) C° for two hours, then reading the level of separation of water from oil and recording these readings within the time (120 minutes). 2.2. Explanatory Work Tables Table 1. Brief the ratios and sizes adopted in the process of separating water from oil pH value Mixing speed(rpm) NaCl (ppm) Temperature C° Sedimentation time (min) Nanomaterials concentration (ppm) Dose injection (ppm) 2 3 4 5 6 7 8 9 10 11 12 6000 10000 12000 250 500 750 1000 1250 1500 1750 15 50 70 100 20 30 60 120 300 600 900 1200 1500 1800 2100 2400 2700 3000 500 1000 1500 2000 2500 3000 3500 Table 2. Crude oil test results (Amara field) before treatment (Al-Dora Refinery) RESULT TEST 23.1 API gravity at 15.6 C 0.9153 SP.GRAVITY at 15.6 C 0.9148 DENSITY at 15C 3.67 SULFUR CONTENT % WT. 34.1 KIN.VISCOSITY CST. at 37.8C 0.7800 SALT CONTENT% WT. 7139.34 SALT CONTENT PPM 11.6 KUOP CHARACTERIZATION FACTOR 7.0 WATER CONTENT VOL.% A. R. M. Al-Karbalai et al. / Iraqi Journal of Chemical and Petroleum Engineering 22,1 (2021) 29 - 38 31 3- The Properties of The Demulsifies Used& Nanomaterial 3.1. The Properties of the Demulsifies Table 3. Characteristics of the demulsifies are used Flash Point C Pour point Viscosity 20 C° (cp) Sp. Gr at 20C° M.W. gm/mol Density gm/ml HLB No. Descript ion Type of Demulsifiers Name of demulsifies 170 °C / / No info-rmation 288.372 1.01 40 White Powder An ionic Sodium dodecyl sulfate(SDS) 154 °C -11 14.0 Cs 1.12 106.12 1.118 6.0 Colorles s liquid Nonionic Diethylene glycol (DEG) 70 C < <-30 C <50 0.94 / / / Brown liquid (ionic)An RB6000 / / / / No further relevant information / / Brown liquid (ionic)An SebaMax 3.2. The Properties of the Nanomaterial Table 4 Characteristics of the SiO2 nanomaterial used surface activity Color and appearance Purity % Densit g/cm3 Mwt(g/mol) Particle size(nm) pH Nanomaterial Negative charged White powder 99.5+ 2.643 60.08 15-20 3.7 SiO2 (Silicon Oxide) 4- Experimental Procedure To know the stability of emulsions in the Amara oil field, it is necessary to note the figure below showing the amount of water droplets dispersed in one drop of oil, thus knowing exactly how to process and the amount of materials to be added during the test. Fig. 1. A real picture for a drop of emulsified oil that is highly stable from the Amara field under an electron microscope (Ministry of Science and Technology - Environment and Water Laboratory) At the beginning of the work, the brine solution is prepared after adding different proportions of ( NaCl salt) with the emulsified oil and the mixing time is for (6 minutes) at different speeds (12,000,6000,10000 rpm) and then the nanomaterial is added (SiO2) at different concentrations each time the treatment process is repeated and mix it with the previous solution for (5 minutes) on (hotplate stirrer), then put the homogeneous solutions after mixing in the test bottle and add demulsifier and close the bottle, then shake it for (3 minutes) by hand, after that it is placed in the water bath at a reservoir temperature of 70 ° C, as shown in Fig. 2. The samples are prepared as follows (oil emulsion with (saltwater) and demulsifiers/nanoparticle):-Four different aqueous solutions were prepared (First mixture: 100g water, 1 wt. % NaCl, and 1 wt. % SDS, and 1 wt. % SiO2 ), (Second mixture: 100g water, 1 wt. % NaCl, and 1 wt. % Diethylene glycol, and 1 wt. % SiO2), (Third mixture: 100g water, 1 wt. % NaCl, and 1 wt. % RB6000, and 1 wt. % SiO2), (Fourth mixture:100g water,1wt.% NaCl, and 1 wt.% SebaMax, and 1 wt. % SiO2), the percentages of water added to the oil were as shown in the table (5). These models are re-equipped with the rest of the demulsifier types, temperatures, and speeds to observe and record the difference in the treatment process and separate the water from the oil. A. R. M. Al-Karbalai et al. / Iraqi Journal of Chemical and Petroleum Engineering 22,1 (2021) 29 - 38 32 Table 5. (water to oil ratio ) Amarah crude oil was added to the aqueous solutions in the bottle test Water to oil ratio 1:9 5:5 7:3 9:1 Fig. 2. Place test bottle samples in the water bath 5- Results and Discussion Sample (a) Sample (b) Sample (c) Fig. 3. Three samples of (w/o) emulsion after treatment over time (30min) (by adding different types of demulsifiers ) with concentration (500 ppm) for demulsifies and a temperature of (50 ° C) with mixing speed (10000 rpm) with (w/o) ratio is(1:9) From left to right (with demulsifiers) 1- The results of the treatment for sample (a) with the demulsifiers type (SDS) showed good separation within a short time when the separation ratio reached (10ml) 2- The results of the treatment for sample (b) with the demulsifiers type (DEG) showed slightly separation within the same time when the separation ratio reached (6ml) 3- The results of treating the sample (c) with the type of demulsifiers (RB6000) showed a significant separation during the same time in which the level of separation was (15 ml). sample (a) sample (b) sample (c) Fig. 4. Three samples of (w/o) emulsion after treatment and a demulsifies (Seba Max) at the concentration (500 ppm), and a temperature of (15 ° C) and (5:5 w/o ratio) From right to left 1-A Sample (c) showed the result of separation at a level of (2ml) after the passage of (20 min) time and at a mixing speed of (10000 rpm) without adding (SiO2). 2-A sample (b) showed a separation result at a level of (5ml) after the passage of (30 min) time and at a mixing speed of (10000 rpm) without adding (SiO2). 3-A Sample (a) showed a better separation result than previous samples with a separation level (17ml) after a (30 min) time and at a lower mixing speed of (6000 rpm) in the presence of the nanomaterial (SiO2=300 ppm). 5.1. Temperature Effect In Fig. 5, the increase in the separation process is proportional to the increase in temperature over time, and the highest level of separation is at a temperature of (70)°C and after (120 minutes). The figure also shows that the wet oil was treated with a demulsifier (SibaMax) with a concentration of (500 ppm), where we notice that the separation rate started at (30)% at the temperature (15)°C and the separation began to increase upward with the rise in temperature to (70)°C which equal to (85%), but when the temperature increased to the maximum at (100 °C), the emulsified oil starts the intensity and stability increases, and transforming into a reverse emulsion, after (120 minutes). A. R. M. Al-Karbalai et al. / Iraqi Journal of Chemical and Petroleum Engineering 22,1 (2021) 29 - 38 33 It is observed that the heat in the process of separating the water from the oil has a basic effect; As it helps to reduce the viscosity of the oil, and the effect of heat in reducing viscosity helps to increase the separation speed by enhancing the fusion of the drops that will form large drops as a result of a collision with each other [12], despite the positive effects of heat on the entire process, there is some negative impact on oil containing light compounds, their evaporation may affect the total volume of oil, as approximately 1% of the total volume is lost, and also the release of these compounds or gases may cause a disruption that hinders the gathering Water droplets and prevents their stability, and this problem is addressed by taking into account the design of the buffer in the field; In new designs, oil is kept above the bubble pressure by placing small insulators above the treatment vessels [13]. Fig. 5. The effect of different temperatures on (water –oil) separation at (500ppm) SebaMax, (10000rpm), (1:9 w/o ratio),NaCl concentration(250ppm), at different temperature (15,50,70,100) °C 5.2. pH effect The pH of water has a strong influence on its emulsion stability (water/oil), the stable hard emulsion film contains organic acids and bases, asphalt, and solids with ionizing groups. The addition of inorganic acids and bases strongly influences their ionization in the interlayers and radically changes the physical properties of the films [14]. The pH of water affects the hardness of the interlayer membranes that need to be fused and precipitate into the bottom for the separation to succeed [15]. In Fig. 6, in which the effect of the pH on the process of separating water from oil and in brine is shown as the pH (2 and 3) represent a stable emulsion that is difficult to separate easily, but with the passage of raising the pH away from the acidic medium and close to the basic direction, we notice the beginning of the separation process significantly compared to the acidic medium and the reason for this difference is due to the separation with the difference in the pH to the attractive forces and the repulsion provided by the salt medium by the presence of an (ionic demulsifiers), where the concentration of the brine solution increases as the pH rises [16]. The other reason for the high separation ratio whenever we exceed the pH value (7 and 8) to the imbalance of the stability of the emulsion and its disorder due to the loss of the surface tension force of the droplets heading towards coalescence, and the formation of larger drops, which leads to their sedimentation at the bottom and their separation from the oil droplets, and as a result of the difference in densities, the oil is up and the water settles down, which means a successful separation process and after 120 minutes have passed, but when the pH value increases more than necessary, we notice that a reverse emulsion is formed, and the separation value returns by dropping to a level lower at (pH = 11 and 12).[17] The amount of pH is variable from distilled water to brine; this difference is due to the effect of ionization (ionic bonding/reaction in brine with asphalt). for most brine systems, there is an ideal pH level at which the membrane surrounding the droplets will exhibit minimal emulsion stability or maximum emulsion fracturing properties, and the pH value (optimal value) depends on two important factors (properties of the crude oil and brine composition). The last factor appears to be the most important. [18] Fig. 6. Effect of pH on separation process at 50 C° with SebaMax at (1500 ppm) in the presence (SiO2=900 ppm),(1200 rpm), NaCl concentration (750 ppm) 5.3. Effect of Injected Dose of Demulsifiers Also, an important factor affecting the emulsion separation process is the amount or dose of demulsifiers added to the emulsified oil mixture. The amount of the added dose affects the success or failure of the separation process, as the large amount is harmful in the treatment process (excessive treatment state) which may cause an emulsion Reverse, while very low doses may lead to treatment failure due to insufficient dose breakage and penetration of the membranes of the drops of saltwater in the emulsified oil. In Fig. 7, the concentrations of the demulsifier (RB6000) ranged from (500ppm) to (2500ppm), where the separation ratio was at the lowest level at the concentration (500 ppm) was (29.7%), while the increase in the separation with the increase in the values of the demulsifier concentrations and reached the highest separation rate It is (75%) at the concentration (2500 ppm). A. R. M. Al-Karbalai et al. / Iraqi Journal of Chemical and Petroleum Engineering 22,1 (2021) 29 - 38 34 Fig. 7. Effect of Injected dose of demulsifier (RB6000) at (50°C),10000 rpm, (water/oil ratio= 7:3), at SiO2 concentration (1800ppm),NaCl concentration (1000ppm) 5.4. Effect of Demulsifies Types In Fig. 8 an illustration of the best separation when using a different group of demulsifiers where the separation ratio increases with (RB6000) and is slightly less than it with the use of the enhanced demulsifiers (SebaMax) and less than with (SDS) after the nanomaterial is mixed (SiO2) with emulsion, the separation ratio increased and the treatment of wet oil was improved. this is due to the ionic surfaces of the demulsifiers, which can attract water droplets after penetration by the solid nanomaterial and thus collect and deposit them as a result of gravity and increase the weight of the droplet, so it is pushed back to the bottom of the bottle test is away from oil droplets and due to different densities, which requires oil to rise and water down. In the case of the (DEG) demulsifiers with a positive (non-ionic) surface, its separation ratio is low compared to the rest of the aforementioned fractions, and it takes a longer time for the treatment result to appear. And for the demulsifier to be effective, it must be mixed well with the emulsion for the molecules of the active chemical to surface to penetrate the flexible membranes surrounding the saline water system drops. If the mixing process is insufficient and slow, then the treatment is futile. The emulsifier breaker should be injected into the crude oil (the continuous phase in the emulsified mixture) typically through (homogeneous mixer at a variable and suitable speed) to form a one-way stream that is sufficient to mix the refractory with the emulsion taking into account the time sufficient for complete mixing [19]. The difference in the separation efficiency of each type of demulsifies is due to the different molecular weights of the polymeric compounds involved in the structure of each type, and consequently the difference in the interaction efficiency with the surfaces of the membranes surrounding the emulsion drop and the reduction of the surface tensile strength as the commercial demulsifiers are more feasible and effective than the local demulsifiers manufactured for treatment purposes with less stable emulsions. The higher of molecular weight of the demulsifiers, the greater the separation efficiency. (RB6000 is the highest molecular weight) despite the lack of information on (RB6000 and Sebamax). Fig. 8. Effect of demulsifies types with (SiO2) at (2100 ppm) concentration of (SiO2) with (2000ppm of demulsifiers) after (2hr),(7:3 water-oil ratio), (250 ppm NaCl) with mixing speed at (12000rpm) in (70°C ). 5.5. Effect of Mixing Speed Speed is an important factor in the wet oil treatment process. Increasing the mixing speed results in a more homogeneous mixture, thus increasing the collision of the mixture particles with the demulsifiers helps to separate faster. Speed is also one of the factors that affect the temperature and increase the pressure on the membranes, as the high speed means the increase in the movement for emulsion droplets, that lead to a decrease in viscosity, so at the speed (12000 rpm) the separation process is faster and greater than the lowest speed (10,000 & 6000 rpm), but when the mixing is increased more than the required limit, we notice that the emulsified oil returns to a reverse emulsion at the speed (13000 rpm) as showing in Fig. 9. Fig. 9. Effect of mixing speed in wet oil separation A. R. M. Al-Karbalai et al. / Iraqi Journal of Chemical and Petroleum Engineering 22,1 (2021) 29 - 38 35 5.6. Nanomaterial Concentration Effect Nanoparticles are the best suggestion when treating hydrocarbons (separating saltwater from oil), and studies have shown that nanoparticle such as (SiO2) can remove oil drops from the emulsion faster compared to conventional separations this is due to the ability of the solid nanomaterial surfaces of a substance (SiO2) to penetrate the water droplet and tear the interstitial membrane that prevents the drops from coalescing and separating them from the oil. Therefore, the solid nanomaterial possesses a high ability to reduce surface tension. It was observed that when using nanoparticles of (SiO2) the separation process with the presence of demulsifies (RB6000, Seba max) is much larger in the test bottle after (40 min) and (120 min), which is the case when separating without nanomaterial, (as shown in Fig. 10. In the image in Fig. 10, an emulsion (water/oil) before and after injection of the nanomaterial (SiO2) where the nanomaterial contributed to tearing the membranes surrounding the water droplet, accumulating it and collecting it, thus depositing it on the bottom away from the oil drop, which made the emulsion less stable Fig. 10. Optical microscope photos of the w / o emulsion(A) 10 minutes, (b) after 40 minutes, (c) after injecting the nanomaterial, and collecting water droplets. In Fig. 11, we notice that the greater concentration of the nanomaterial added to the emulsion sample resulting greater the separation process over time, at the lowest concentration of nanomaterial which is (300 ppm) the separation ratio was lowest and equal to (20%), while the separation percentage reached the highest (88%) at the concentration (2700 ppm) after 120 minutes, while when the concentration increased above the permissible limit to ( 3000 ppm), the wet oil returns a reverse emulsifier. Fig. 11. Nanomaterial concentration effect 5.7. Salinity Effect The salt concentration added to the emulsified oil has a major effect on the membrane droplet of saltwater in crude oil. The crude oil extracted from the reservoir is usually accompanied by water droplets in the form of a highly stable emulsion [20] . This salty water present in the oil contains asphalt, waxy materials, and other impurities, which are one of the factors that stabilize the emulsion. Asphalt plays a major role in forming the film or the interlayer that increases the repulsion forces between the water droplets [21], so comes the role of (NaCl) in tearing these membranes surrounded by water droplets and releasing them from repulsive forces to attract and integrate them and thus sediment them at the bottom of the test bottle and calculate the separation ratios, it has been observed that the higher TDS factor increases the separation.[22] In other words, the results (bottle test) showed that the optimal concentration of the nano emulsification fraction increased its efficiency when increasing the concentration of salt (NaCl), as the (distribution of the size of the droplet DSD) increased as a result of adding salt and this increase is accompanied by a decrease in the emulsion viscosity, which leads to reduced emulsion stability [23]. Also, this increase is accompanied by an increase in the spread of small droplets and their precipitation over the larger droplets, thus increasing the drop's weight and fusion, which means its deposition at the bottom, which in turn increases the efficiency of the nanomaterials added to break the stable emulsion as in Fig. 12. Fig. 12. The effect of salinity ( from 250 to 1750 ppm) of NaCl ) after 120 min at (2000 ppm concentration of Sebamax demulsifier) at 70 C° and (1000rpm) with (5:5 water-oil ratio), with a fixed concentration of nanomaterial (SiO2) equal (1800ppm) 5.8. Effect of Surfactant Here it must be noted that the treatment method in the Amara oil field is limited to the use of commercial demulsifiers (RB6000 & Sebamax) without any chemical additives that support the separation and treatment process. A. R. M. Al-Karbalai et al. / Iraqi Journal of Chemical and Petroleum Engineering 22,1 (2021) 29 - 38 36 In this paper, it had been focused on studying the effect of adding nanomaterial (SiO2) and its support for demulsifiers in the wet oil treatment process, where it was observed that the relationship between surface stimuli (ionic –SiO2) and demulsifiers is linear (23), which means that if we increase the surfactant twice, this corresponds to a doubling increase in the amount of demulsifiers needed to break down the emulsion, as shown in Fig. 13 Fig. 13. Effect of surfactant (SiO2) on demulsifier performance 6- Conclusions The asphaltic functional groups become charged, which enhances the repulsion of the droplets and increases the elasticity of the interlayer, and the surface tension increases, and here comes the role of factors (pH and NaCl) in changing the charge of ions surrounding the water droplet membrane, so the electrostatic stability decreases, which helps the water droplets merge, which is a stage (Coalescence ( Heat and mixing speed have a major effect on reducing the viscosity of the oil and thus ease of processing and breaking emulsification, and the separation efficiency increases if the (SiO2) nanomaterial is added with the emulsification breaker (RB600 and SebaMax) and less than that with (SDS and DEG) as in Fig. 8 The separation process is stabilized after two hours under precise laboratory conditions. 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Al-Karbalai et al. / Iraqi Journal of Chemical and Petroleum Engineering 22,1 (2021) 29 - 38 38 ( مع انواع SiO2معالجة النفط الرطب في حقل العمارة النفطي باستخدام المادة النانوية) من كواسر االستحالب غسان حميد عبدالمجيد3و عادل شريف حمادي2آيات راغب الكربالئي, 1 قسم تكنولوجيا النفط / كلية الهندسة / الجامعة التكنولوجية 1 قسم الهندسة الكيميائية / كلية الهندسة / الجامعة التكنولوجية 2 م العالي والبحث العلمي / بغداددائرة البحث والتطوير / وزارة التعلي 3 الخالصة تدفقه هو النفط المستحلب )الماء في النفط( والذي بدوره من أهم المشاكل في عملية إنتاج النفط وعند استمرار يسبب العديد من المشاكل ، من خط اإلنتاج إلى األنابيب الممتدة التي يتم نقلها بعد ذلك إلى مصفى النفط ( تدعم عملية الفصل بإضافتها إلى عينة المستحلب وأظهرت ارتفاًع SiO2و لوحظ أن المادة النانوية ) للمعالجة. و 90( حيث كانت نسبة الفصل أكبر من )sebamax( و )RB6000دل الفصل مع كواسر االستحالب )مع Sodium Dodecyl Sulfate and Di Ethylene (٪ على التوالي ، وأقل من ذلك عند التعامل مع )80 Glycol ( كانت النسبة المئوية للفصل ، )ن )ترفع النسب العالية م ٪( على التوالي.50٪ و 60NaCl الماء + ، RB6000(٪ لـ )55، 65.5(٪ و )88.5,79المقطر( من احتمال كفاءة الفصل حيث كان الفصل ) SebaMax( على التوالي مع )SiO2 ( لـ 65،40(٪ و )77،85درجة مئوية ، بينما كانت نتائج الفصل ) 70( عند (RB6000 ،Seba Max( على التوالي مع )SiO2 عند )دقيقة ، حيث كانت )نسبة 120درجة مئوية بعد 50 دورة في الدقيقة( 12000( لنتائج الفصل األقل بسرعة )3: 7( لنتائج الفصل المرتفعة و )1: 9الماء / الى النفط( ) يتعامل ملح ( جزء في المليون وأقل من هذه النتائج في الظروف الحجمية والزمنية المنخفضة.1500وبتركيز ملح ) أما بالنسبة لعامل األس الهيدروجيني ، يد الصوديوم مع أغشية الجدار الذي يفصل القطرات ويقلل من لزوجتها.كلور ( يمثل مستحلًبا ثابًتا يصعب فصله بسهولة ، ولكن مع مرور ارتفاع الرقم الهيدروجيني بعيًدا 3و 2فهو عند القيمة ) ن زيادة واضحة في عملية الفصل لوحظت مقارنة مع الوسط عن الوسط الحمضي وقريًبا من االتجاه القاعدي ، فإ ( ٪ على التوالي ، بينما 70و 60دقيقة بدا الفصل جيد الكفاءة ، حيث وصل إلى ) 120الحمضي بقيم أقل ، بعد و 80( يساوي )7و 8يني )وصل المستحلب في نفس الوقت إلى مستوى فصل أكثر كفاءة مع الرقم الهيدروج وبنفس قيم األس الهيدروجيني ، (،SiO2بوجود ) SebaMaxدرجة مئوية مع كاسر استحالب 50، عند ( 87.3٪ .درجة مئوية( 70لوحظ زيادة في الفصل مع زيادة درجة الحرارة إلى ) : مستحلب, كاسر استحالب, نفط خام , مستحلب )الماء/في النفط(, مادة نانوية, ماء مالحالدالة الكلمات