Available online at http://ijcpe.uobaghdad.edu.iq and www.iasj.net Iraqi Journal of Chemical and Petroleum Engineering Vol.21 No.1 (March 2020) 45 – 52 EISSN: 2618-0707, PISSN: 1997-4884 Corresponding Authors: Name: Laith Warid Farhan , Email: laith.wared@gmail.com , Name: Faleh H. M. Almahdawi , Email: fhmetr@yahoo.com , Name: Adel Sherif Hammadi, Email: 80013@uotechnology.edu.iq IJCPE is licensed under a Creative Commons Attribution-NonCommercial 4.0 International License. Dissolving Precipitated Asphaltenes Inside Oil Reservoirs Using Local Solvents Laith Warid Farhan a ,Faleh H. M. Almahdawi a and Adel Sherif Hammadi b a Petroleum Engineering Department/ College of Engineering/ University of Baghdad, Iraq b Petroleum technology department/university of technology, Iraq Abstract There are several oil reservoirs that had severe from a sudden or gradual decline in their production due to asphaltene precipitation inside these reservoirs. Asphaltene deposition inside oil reservoirs causes damage for permeability and skin factor, wettability alteration of a reservoir, greater drawdown pressure. These adverse changing lead to flow rate reduction, so the economic profit will drop. The aim of this study is using local solvents: reformate, heavy-naphtha and binary of them for dissolving precipitated asphaltene inside the oil reservoir. Three samples of the sand pack had been prepared and mixed with a certain amount of asphaltene. Permeability of these samples calculated before and after mixed with asphaltenes. Then, the permeability of samples calculated after solvents injection into that porous media. After that, all the values of samples permeability converted to average permeability damage compared with the pure samples. The results show the average permeability damage of samples that mixed with 20 gm was 24 %, but after reformate injected reduced to 14 %. After injected heavy naphtha to porous media, the average permeability reduced only to 17%. The binary solvent had been prepared from reformatted mixed with heavy naphtha gained the best results because it dropped the average permeability damage to 10%. Keywords: asphaltene deposition, Iraqi local solvents, permeability damage, oil reservoirs, reformates heavy naphtha. Received on 04/09/2019, Accepted on 01/11/2019, published on 30/03/0220 https://doi.org/10.31699/IJCPE.2020.1.7 1- Introduction This decrease in permeability within the reservoir is called formation damage. There are many types of formation damage that are mainly divided into organically produced by chemical reactions between the rock and fluids or fluids among them, either the second type is mechanical which arises due to production or drilling operations due to force and movement‎[1]. There are many ways to increase permeability, including acidizing of the layer by injecting organic acids such as Hydrochloric Acid (HCl) and Hydrofluoric acid (HF) into the layer for scrubbing pore surfaces and thus increase permeability. Another method is hydraulic fracturing, which is done through high-pressure liquid injection to reservoir formation and as a result, the permeability increases ‎[2]. One of the serious damage cases is the deposition of asphaltenes inside the reservoir that generate organic damage to permeability. Asphaltenes deposition probably occurs inside the reservoir or inside the production pipes or in the surface facilities. For the purpose of removing the asphaltenes inside the reservoir, a solvent such as toluene or benzene is injected for dissolving it in the pores and thus restore the unaffected permeability ‎[3]. It is worth noting that the problem of asphaltenes is a global problem that occurs in both light and heavy oil reservoirs. This problem has caused a huge economic loss because it is working to significantly reduce oil production. Many of the Iraqi fields suffer from this issue, as happens in the Bazargan field and the East Baghdad field. The main reason for the possible deposition of asphaltene is the chemical composition of the oil. So to know the stability of asphaltene in crude oil must know the compounds of crude oil. The percentage of saturated, resin, aromatic and asphaltene compounds that presence in the crude oil then analyzed these compounds by a process called SARA analysis. Oil components either measure by ASTM test or by nuclear magnetic resonance (NMR). Crude oil components: saturates, resins, aromatics, and asphaltenes can be predicted by nuclear magnetic resonance by measuring aromatic hydrogen and aromatic carbon for crude oil. SARA analysis is an analytical method for the crude oil components by which the stability of the asphaltene is revealed. This method includes calculating the values of certain variables and these variables reflect the stability of crude oil ‎[4], ‎[5]. Four types of damage are caused by the formation of asphaltenes inside the porous media ‎[6]:  Reduce permeability.  Change of wettability.  The decrease in viscosity of crude oil.  Formation of water emulsions in oil. https://doi.org/10.31699/IJCPE.2020.1.7 L. W. Farhan et. al. / Iraqi Journal of Chemical and Petroleum Engineering 21,1 (2020) 45 - 52 64 1.1. Permeability Measurements Permeability is the property of the porous medium that dealing with the capacity and capability of the formation to conduct fluids flow. It director directional movement and flow rate of fluid flow ‎[7]. Darcy developed equation represented the fluid flow through a porous medium and it became one of the most popular equations in reservoir engineering. This equation found in many forms, one of them the following formula for horizontal linear incompressible flow through a porous medium ‎[8]: (1) Q = flow rate, cm/s. K = permeability, Darcy. A = cross-sectional area, cm 2 . µ = viscosity, (cP) L = length of core sample, cm. ∆P = pressure drop, atm. There are many assumptions to the above equation includes ‎[8]:  The direction of flow is horizontal.  The regime of flow is laminar.  There is a fluid in a porous medium.  Between rock and fluid should not be a chemical process. Reservoir rock with a high value of permeability leads to produce a large amount of commercial oil and gas for a long period. In contrast, reservoir rock with low permeability may not able to produce a large quantity of oil and gas. Because one Darcy is a very high value for reservoir rock, milliDarcy is a more common unit in permeability calculation ‎[7]. Worthwhile, The relationship between core and well log data was determined by Artificial Neural Network (ANN) in cored wells to develop the predictive model and then was used to develop the flow unit prediction to un-cored wells ‎[9]. There are factors affecting permeability values ‎[10]:  Shape and size of sand grain: Rock with small flat grains has less permeability from the rock with the large rounded grain.  Lamination: rock with shale lamination has less permeability than layers without lamination.  Cementation: porosity and permeability affected by the type and position of cementation within the rock. The permeability of rock describe according to Table 1: Table 1. Description of permeability values ‎[11] Permeability range, mD Permeability description Poor Fair Moderate Good Very good There are too many sources of permeability data include ‎[12]:  Core sample laboratory measurement.  Nuclear magnetic response (NMR).  Drill stem test and other well pressure tests.  Well logging with indirect methods.  Correlations that attempt to forecast permeability from porosity values.  Geostatistical techniques attempt to predict permeability with spatial variation. 2- Experimental Work 2.1. Materials a. Crude Oil The physical oil properties of crude oil from Tannumah illustrated in Table 2 after provided from Midland Oil Company Table 2. Physical oil properties of a sample Property Value Specific gravity 0.922 API gravity 22 Viscosity at 37 C, cP 31 Saturate compounds, % wt. 42.3 Aromatic compounds, % wt. 26.7 Resin compounds, % wt. 18.2 Asphaltene compounds, % wt. 12.8 b. Toluene According to (HSDB, 1991) “Toluene is a combustible, colorless, anticorrosive fluid as the same as benzene odor". It is unsolvable in water and solvable in acetone, absolute alcohol, ether, chloroform, benzene, petroleum ether, glacial acetic acid, and carbon disulfide)”. Toluene's molecular formula is C7H8. c. Hexane The n-hexane used in these experiments had been gotten from AL-Dura Refinery. Hexane represents a precipitant liquid for asphaltene. It used to illustrate the effect of solvent in reduced asphaltene deposition. The molecular formula of hexane is C6H14. d. Reformate Reformate is a solvent liquid for asphaltenes. Reformate had been gotten from AL-Dura Refinery. The properties of reformate that used in this study shown in Table 3. L. W. Farhan et. al. / Iraqi Journal of Chemical and Petroleum Engineering 21,1 (2020) 45 - 52 64 Table 3. Properties of reformate API 61.7 Specific gravity at 60F°/60 F° 0.733 Sulfur Content 3 ppm ASTM distillation The distillate,vol% Boiling point(C°) 60 88 94 106 110 117 124 132 140 147 178 IBP 10 20 30 40 50 60 70 80 90 FB e. Heavy Naphtha Heavy Naphtha is a solvent liquid for asphaltenes. Reformate had been gotten from AL-Dura Refinery. The properties of reformate that used in this study shown in Table 4. Table 4. Properties of heavy naphtha API 54.9 Specific gravity at 60F°/60 F° 0.759 Boiling range(C°) (90 – 180) C BTX content, vol % Benzene Toluene P and M xylene O-xylene 3.18 14.94 17.66 11.58 ASTM distillation The distillate,vol% Boiling point(C°) 43 71 80 86 92 97 103 110 121 144 154 180 IBP 10 20 30 40 50 60 70 80 90 95 FB Nanotechnology has shown a lot of promise in the oil and gas sectors, including nanoparticle-based drilling fluids ‎[13]. So, the Nano surfactant materials recommended for use. 2.2. Sand Sand has been used to make the sand packing with magnitude scattering of 80 to 500 µm. 2.3 Fluid injection system All the experiments related to testing flow rate and pressure through the core sample needed to the fluid injection system. The accuracy of that system is too sensitive. So, the price of an accurate system reaches to 500,000$. This study building on a simple system consists of the reservoir tank, core holder, water bath and Co2 bottle. a. Reservoir tank and accessories A container tank has been made from the carbon steel layer (5 mm thickness) inorder to resist high pressures. All the joints tools manufactured from Tungsten so as to bear the high pressures. That apparatus holds two orifices, the first on the roof of the container with a gate valve (inlet) to fill up the tank by either oil, water or solvents, the other passageway to transfer the fluids to the core holder. b. Core holder Core Holder is composed of a high-pressure tube that has 1.5 " an internal diameter. It connects with the container tank from side and tape from the other side. As well it is made up of a pipe that has an external diameter of 1.5" (38 mm) and an internal diameter of ( 30 mm). it manufactured of anti-corrosion stainless steel to prevent corrosion error. Besides, it provided with very fine filter bond inner the pipe to stop of sand pack movement or sand grains along the pipes. c. CO2 bottle A Co2 2000 psi bottle has been used through the experiments to move fluids into the sand pack d. Check valve The check valve has been used to push the fluid forward only and pressurized the contained fluid. e. Heater Used for heating the injected fluids through the system. it put on the route vessel. That vessel bearing a high boiling point has been placed over this heater. f. Pressure Differential Gauge Used for measuring the pressure drop along with the sand pack with upper limit reading 3000 psi. g. Thermometer A thermometer is a tool that measures temperature or a temperature gradient. The fluid injection system and its part illustrated in Fig. 1, Fig. 2 and Fig. 3. L. W. Farhan et. al. / Iraqi Journal of Chemical and Petroleum Engineering 21,1 (2020) 45 - 52 64 Fig. 1. Fluid injection system design Fig. 2. Fluid injection system Fig. 3. Core holder of the fluid injection system 2.4. The Procedure of the Fluid Injection Experiment a. The Preparation of Sand Pack Sand granules with sizes between 80 and 500 are washed and dried. In some cases the sand mixed with a certain weight from asphaltene to reduce permeability and shown the effect of asphaltene on permeability calculations, then placed inside the tube ends with a filter from both sides to prevent sand leaking out and allowing the fluid to pass into and out of the tube. b. The Preparation of Injected Fluid The crude oil with or without solvents were injected to sand pack for showing the permeability changes that occurred due to the presence of solvents. The stirrer device has been used to make homogenously mixed fluid. c. Permeability measurements Using Darcy’s Law, the permeability of the sand pack in different cases has been calculated. The equation of Darcy’s law shown below: (1) Q = flow rate, cm/s. K = permeability, Darcy. A = cross-sectional area, cm 2 . µ = viscosity, (cP) L = length of core sample, cm. ∆P = pressure drop, atm. The constants of Darcy’s law-related with this study shown in Table 5. Table 5. Darcy’s equation input parameter value unit Cross sectional area 7.068 cm 2 Length of the core holder 10 cm Viscosity of water 1 cP Viscosity of oil 31 cP The viscosity of the oil-reformate mixture 28.34 cP The viscosity of oil- heavy naphtha mixture 26.61 cP The viscosity of oil- reformate-heavy naphtha mixture 27.21 cP 3- Results and Discussion 3.1. 3.1. Permeability of Sand Packs in Different Cases 2.0. Asphaltenes represent the cholesterol of petroleum engineering because it blocks the passageway of movable oil. It adversely affects the permeability property of rocks, no doubt lead to production reduction. To illustrate the effect of asphaltene and solvents that injection for asphaltene dissolving must measure the original permeability, the damaged permeability, and the recovered permeability. The study depends on eleven different cases for the illustration of its goal. L. W. Farhan et. al. / Iraqi Journal of Chemical and Petroleum Engineering 21,1 (2020) 45 - 52 64 These cases are shown in Table 6. In each case, the sand pack fully saturated with injection liquid for 1 hour for precipitant or dissolve asphaltene then reinjection the same liquid for permeability measurement purposes. Table 6. Cases of permeability measurements Case number Rock state Injection fluids 1 Sands water 2 Sand + 20 gm Asphaltene Oil 3 Sand + 20 gm Asphaltene Crude oil 80 % + n- hexane 20 % 4 Sand + 20 gm Asphaltene Crude oil 80%+ reformate 20 % 5 Sand + 20 gm Asphaltene Crude oil 80 % + heavy naphtha 20 % 6 Sand + 20 gm Asphaltene Crude oil 80 % + heavy naphtha 10 % + reformate 10 % a. Case 1 Using the injection system, the permeability of three pure sand packs calculated. Pressing crude oil that presence in container tank by co2 bottle stimulates the oil to enter the core holder. Measure the pressure in inlet and outlet give differential pressure. Measure the volume and time given flow rate. The results are shown in Table 7. The difference in permeability between three sand pack samples belongs to the difference in flow rate and pressure drop. The last difference result from the unlike composite of each simple Table 7. Permeability calculations of case 1 sample V t Q ∆P k No. cm 3 sec. cm 3 / sec. (cm cP)/sec. atm. atm./cm Darcy 1 33.2 10 3.32 0.47 4.2 0.42 1.123 2 33.8 10 3.39 0.48 4.7 0.47 1.027 3 32.5 10 3.25 0.46 5.2 0.52 0.89 b. Case 2 To illustrate the effect of asphaltene precipitated on permeability, the sand pack sample mixed with 20 gm of dry asphalt. The results are shown in Table 8. The average permeability damage was 24 % that means a quarter of well production performance declined. It calculated from this equation: ( ) ∑ ( ) ( ) ∑ ( ) (2) Table 8. Permeability calculations of case 2 Sample V t Q ∆P k No. cm 3 sec. cm 3 / sec. (cm cP)/sec. atm. atm./cm Darcy 1 16 60 0.27 1.18 13.6 1.36 0.868 2 16 60 0.27 1.18 15.5 1.55 0.764 3 15 60 0.25 1.09 16.8 1.68 0.651 c. Case 3 To illustrate the effect of n-hexane (precipitant) on crude oil, case 4 includes mixed 80 % crude oil and 20 % n-hexane. Also, sand packs mixed with 20 gm dry asphaltene. The results are shown in the 9 with 48% average permeability reduction. That means almost half of the production performance dropped. Table 9. Permeability calculations of case 3 sample V t q ∆P k No. cm 3 sec. cm 3 / sec. (cm cP)/sec. atm. atm./cm Darcy 1 15 60 0.25 1.09 17.1 1.71 0.64 2 12.5 60 0.2 0.87 17.5 1.75 0.5 3 12.5 60 0.2 0.87 20 2 0.437 d. Case 4 Sand pack mixed with 20 gm of dry asphalt. Also crude oil in this case mixed with reformates solvent (80 % wt. crude oil + 20 % wt. solvent). The results are shown in Table 10. The average production damage was 14 %. That means only 14 %of production performance declined, while in case two was 24 % that similar to this case apart from fluids there is only crude oil without solvent. Table 10. Permeability calculations of case 4 Sample V t Q ∆P k No. cm 3 sec. cm 3 / sec. (cm cP)/sec. atm. atm./cm Darcy 1 10.8 60 0.18 0.74 8.2 0.82 0.901 2 11.4 60 0.19 0.78 9 0.9 0.873 3 12 60 0.2 0.79 9.5 0.95 0.832 e. Case 5 Another solvent used to remove the asphaltene particle is heavy naphtha. In this case, mixed of 80 % crude and 20 %, heavy naphtha injected to sand packs mixed with 20 gm of dry asphalt. The results of this experiment were shown in Table 11. The average permeability damage was 17 %. That means only 17 % of production performance declined, L. W. Farhan et. al. / Iraqi Journal of Chemical and Petroleum Engineering 21,1 (2020) 45 - 52 05 while in case two was 24 % that similar to this case excluding for fluids, there is only crude oil without solvent. Table 11. Permeability calculations of case 5 Sample V t Q ∆P k No. cm 3 sec. cm 3 / sec. (cm cP)/sec. atm. atm./cm Darcy 1 11.1 60 0.185 0.7 8.3 0.83 0.844 2 12 60 0.2 0.75 8.9 0.89 0.844 3 12 60 0.2 0.79 9.7 0.97 0.818 f. Case 6 Binary solvent from 10 % heavy naphtha and 10 % reformate was prepared and mixed with 80 % crude oil. Sand packs also mixed with 20 gm dry asphalt. The results of these experiments were shown in Table 12. The average permeability damage was 10 %. That means only 10 % of production performance dropped, whereas, in situation two was 24 % that similar to this situation with the exception of fluids, there is only crude oil without solvent. Table 12. Permeability calculations of case 6 Sample V T Q ∆P k No. cm 3 sec. cm 3 / sec. (cm cP)/sec. atm. atm./cm Darcy 1 10.8 60 0.18 0.68 7.2 0.72 0.948 2 12 60 0.2 0.78 8.5 0.85 0.917 3 12 60 0.2 0.78 9 0.9 0.872 3.2. Average Permeability Damage After measure permeability damage in each case compares it with initial permeability using the equation. The higher average permeability damage means higher production performance damage. The results are shown in Table 13 and in Fig. 4. Table 13. Summary of average permeability damage Case Average Permeability Damage No. % 2 24 4 48 6 14 8 17 10 10 Fig. 4. Summary of average permeability damage From figure these points are observed:  The first five values represent the higher permeability damage due to the absence of the solvents within the sand packs.  Presence n-hexane in 4 and 5 cases gave more average permeability damage than other cases due to the precipitant characteristics of n-hexane.  The effectiveness of the solvents used in the study in preventing and dissolving the asphaltenes according to the preference as follows: (3) 4- Conclusions a. Solvent quality order in preventing the deposition of the asphaltenes, respectively: binary of reformate- heavy naphtha, then reformate, the less profitable was heavy naphtha. b. Solvents have a great influence to reduce average permeability damage. Solvents dissolve the asphaltene that leads to minimizing the advertising effect of asphaltenes. Recommendation a. Using real cores and plugs damaged with asphaltenes instead of using the sand pack. The cores and plugs prefer to be different types of reservoir rock such as sandstone and limestone. b. Working an economical model for real field case for knowing the optimization quantity and types of solvent required for injection. c. Working on an accurate fluid injection system from a global company consists of digital meters and a piston pump. Acknowledgments I would like to thank my supervisor Assist Prof. Dr. Faleh H. M. Almahdawi for his kindness and forgiveness in a critical stage in this study. Furthermore, all his care and advice contributed to all the good work in this study. 0 20 40 60 1 2 3 4 5 A ve ra g e p e rm e a b il it y d a m a g e ,% Case number Average permeability damage L. W. Farhan et. al. / Iraqi Journal of Chemical and Petroleum Engineering 21,1 (2020) 45 - 52 05 Nomenclature ∆P pressure drop, atm. µ viscosity, (cP) A cross-sectional area, cm 2 . ASTM American Society for Testing and Materials BTX benzene, toluene and xylene HCL hydrochloric HF hydrofluoric K permeability, Darcy. L length of the core sample, cm. Q flow rate, cm/s. References [1] Donnez, Pierre. Essentials of reservoir engineering. Vol. 2. Editions Technip, 2012. [2] Guo, Boyun. Petroleum production engineering, a computer-assisted approach. Elsevier, 2011. [3] JG Speight The chemistry and technology of petroleum. CRC press, 2014. [4] Sanchez-Minero, Felipe, et al. "Predicting SARA composition of crude oil by means of NMR." Fuel 110 (2013): 318-321. [5] S. A. Mohammed and S. D. Maan, “The Effect of Asphaltene on the Stability of Iraqi Water in Crude Oil Emulsions”, ijcpe, vol. 17, no. 2, pp. 37-45, Jun. 2016. [6] Leontaritis, K. J., J. O. Amaefule, and R. E. Charles. "A systematic approach for the prevention and treatment of formation damage caused by asphaltene deposition." SPE Production & Facilities 9.03 (1994): 157-164. [7] Ahmed, Tarek. Reservoir engineering handbook. Gulf Professional Publishing, 2010. [8] B. Craft, M. Hawkins, R. Terry, Applied Petroleum Reservoir Engineering, seconded., Prentice Hall,1990. [9] D. Alobaidi, “Permeability Prediction in One of Iraqi Carbonate Reservoir Using Hydraulic Flow Units and Neural Networks”, ijcpe, vol. 17, no. 1, pp. 1-11, Mar. 2016. [10] Schön, Jürgen H. Physical properties of rocks: Fundamentals and principles of petrophysics. Vol. 65.Elsevier,2015. [11] Tiab, Djebbar, and Erle C. Donaldson. Petrophysics: theory and practice of measuring reservoir rock and fluid transport properties. 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Saad, “Enhancement of Drilling Fluid Properties Using Nanoparticles”, ijcpe, vol. 19, no. 2, pp. 21-26, Jun. 2018. http://www.editionstechnip.com/en/catalogue-detail/1159/essential-of-reservoir-engineering-vol-2.html http://www.editionstechnip.com/en/catalogue-detail/1159/essential-of-reservoir-engineering-vol-2.html https://books.google.iq/books?hl=en&lr=&id=LKn-oVIHXDUC&oi=fnd&pg=PP1&dq=%5B2%5D%09Guo,+Boyun.+Petroleum+production+engineering,+a+computer-assisted+approach.+Elsevier,+2011.&ots=43AVQ1RE0B&sig=xxBaKtG7oFb0lAbDfX_od8Q1e3I&redir_esc=y#v=onepage&q=%5B2%5D%09Guo%2C%20Boyun.%20Petroleum%20production%20engineering%2C%20a%20computer-assisted%20approach.%20Elsevier%2C%202011.&f=false https://books.google.iq/books?hl=en&lr=&id=LKn-oVIHXDUC&oi=fnd&pg=PP1&dq=%5B2%5D%09Guo,+Boyun.+Petroleum+production+engineering,+a+computer-assisted+approach.+Elsevier,+2011.&ots=43AVQ1RE0B&sig=xxBaKtG7oFb0lAbDfX_od8Q1e3I&redir_esc=y#v=onepage&q=%5B2%5D%09Guo%2C%20Boyun.%20Petroleum%20production%20engineering%2C%20a%20computer-assisted%20approach.%20Elsevier%2C%202011.&f=false https://books.google.iq/books?hl=en&lr=&id=Pp_AAgAAQBAJ&oi=fnd&pg=PP1&dq=%5B3%5D%09Speight,+James+G.+The+chemistry+and+technology+of+petroleum.+CRC+press,+2014.&ots=SqYF4mG-bB&sig=GFN8lRiod3Jq8Os1TFvGtC82ymU&redir_esc=y#v=onepage&q=%5B3%5D%09Speight%2C%20James%20G.%20The%20chemistry%20and%20technology%20of%20petroleum.%20CRC%20press%2C%202014.&f=false https://books.google.iq/books?hl=en&lr=&id=Pp_AAgAAQBAJ&oi=fnd&pg=PP1&dq=%5B3%5D%09Speight,+James+G.+The+chemistry+and+technology+of+petroleum.+CRC+press,+2014.&ots=SqYF4mG-bB&sig=GFN8lRiod3Jq8Os1TFvGtC82ymU&redir_esc=y#v=onepage&q=%5B3%5D%09Speight%2C%20James%20G.%20The%20chemistry%20and%20technology%20of%20petroleum.%20CRC%20press%2C%202014.&f=false https://www.sciencedirect.com/science/article/pii/S0016236112008241 https://www.sciencedirect.com/science/article/pii/S0016236112008241 https://www.sciencedirect.com/science/article/pii/S0016236112008241 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/80 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/80 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/80 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/80 https://www.onepetro.org/journal-paper/SPE-23810-PA https://www.onepetro.org/journal-paper/SPE-23810-PA https://www.onepetro.org/journal-paper/SPE-23810-PA https://www.onepetro.org/journal-paper/SPE-23810-PA https://www.onepetro.org/journal-paper/SPE-23810-PA http://booksdl.org/get.php?md5=D3486FD74061537FBE643ECAF7EDFE18&key=AA80D5F8VQXFJH71. http://booksdl.org/get.php?md5=D3486FD74061537FBE643ECAF7EDFE18&key=AA80D5F8VQXFJH71. http://booksdl.org/get.php?md5=fad5293ff053f2f0f1cb2dd9fdffc2b8&key=ZU2PK4B2UUO9LTG9. http://booksdl.org/get.php?md5=fad5293ff053f2f0f1cb2dd9fdffc2b8&key=ZU2PK4B2UUO9LTG9. http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/85 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/85 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/85 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/85 https://books.google.iq/books?hl=en&lr=&id=uckHBgAAQBAJ&oi=fnd&pg=PP1&dq=%5B10%5D%09Sch%C3%B6n,+J%C3%BCrgen+H.+Physical+properties+of+rocks:+Fundamentals+and+principles+of+petrophysics.+Vol.+65.Elsevier,2015.&ots=Ra0xSvsbAk&sig=oofIqqJxg2k6FkwwdpEwhE3kRNA&redir_esc=y#v=onepage&q=%5B10%5D%09Sch%C3%B6n%2C%20J%C3%BCrgen%20H.%20Physical%20properties%20of%20rocks%3A%20Fundamentals%20and%20principles%20of%20petrophysics.%20Vol.%2065.Elsevier%2C2015.&f=false https://books.google.iq/books?hl=en&lr=&id=uckHBgAAQBAJ&oi=fnd&pg=PP1&dq=%5B10%5D%09Sch%C3%B6n,+J%C3%BCrgen+H.+Physical+properties+of+rocks:+Fundamentals+and+principles+of+petrophysics.+Vol.+65.Elsevier,2015.&ots=Ra0xSvsbAk&sig=oofIqqJxg2k6FkwwdpEwhE3kRNA&redir_esc=y#v=onepage&q=%5B10%5D%09Sch%C3%B6n%2C%20J%C3%BCrgen%20H.%20Physical%20properties%20of%20rocks%3A%20Fundamentals%20and%20principles%20of%20petrophysics.%20Vol.%2065.Elsevier%2C2015.&f=false https://books.google.iq/books?hl=en&lr=&id=uckHBgAAQBAJ&oi=fnd&pg=PP1&dq=%5B10%5D%09Sch%C3%B6n,+J%C3%BCrgen+H.+Physical+properties+of+rocks:+Fundamentals+and+principles+of+petrophysics.+Vol.+65.Elsevier,2015.&ots=Ra0xSvsbAk&sig=oofIqqJxg2k6FkwwdpEwhE3kRNA&redir_esc=y#v=onepage&q=%5B10%5D%09Sch%C3%B6n%2C%20J%C3%BCrgen%20H.%20Physical%20properties%20of%20rocks%3A%20Fundamentals%20and%20principles%20of%20petrophysics.%20Vol.%2065.Elsevier%2C2015.&f=false Tiab,%20Djebbar,%20and%20Erle%20C.%20Donaldson.%20Petrophysics:%20theory%20and%20practice%20of%20measuring%20reservoir%20rock%20and%20fluid%20transport%20properties.%20Gulf%20professional%20publishing,%202015. Tiab,%20Djebbar,%20and%20Erle%20C.%20Donaldson.%20Petrophysics:%20theory%20and%20practice%20of%20measuring%20reservoir%20rock%20and%20fluid%20transport%20properties.%20Gulf%20professional%20publishing,%202015. Tiab,%20Djebbar,%20and%20Erle%20C.%20Donaldson.%20Petrophysics:%20theory%20and%20practice%20of%20measuring%20reservoir%20rock%20and%20fluid%20transport%20properties.%20Gulf%20professional%20publishing,%202015. Tiab,%20Djebbar,%20and%20Erle%20C.%20Donaldson.%20Petrophysics:%20theory%20and%20practice%20of%20measuring%20reservoir%20rock%20and%20fluid%20transport%20properties.%20Gulf%20professional%20publishing,%202015. http://booksdl.org/get.php?md5=8F353D14D93FDBF72E5A14315F6F2F2E&key=VZYQJGAGSZ1RSX2L. http://booksdl.org/get.php?md5=8F353D14D93FDBF72E5A14315F6F2F2E&key=VZYQJGAGSZ1RSX2L. http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/162 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/162 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/162 http://ijcpe.uobaghdad.edu.iq/index.php/ijcpe/article/view/162 L. W. Farhan et. al. / Iraqi Journal of Chemical and Petroleum Engineering 21,1 (2020) 45 - 52 05 أذابة االسفمت المترسب داخل المكامن النفطية بأستخدام مذيبات محمية 2و عادل شريف 1فالح المهداوي , 1ليث وارد 1 جامعة بغداد, كمية الهندسة, قسم هندسةالنفط1 الجامعة التكنولوجية, قسم تكنولوجيا النفط2 الخالصة هناك العديد من المكامن النفطية التي تعاني من فقدان تدريجي او مفاجئ لالنتاج بسبب ترسب االسفمت داخل تمك المكامن. ترسب االسفمت داخل المكامن النفطية يؤدي الى التضرر الطبقي وتغير التبممية المكمنية فقدان الضغط وكل هذا يؤدي الى انخفاض قيم االنتاج وبالتالي انخفاض القيمة االقتصادية لممشروع. وزيادة الهدف من هذه الدراسة هو استخدام مذيبات محمية ألذاية ترسبات االسفمت داخل المكامن النفطية. ثالث انواع حدد منهما. ثالث نماذج حضرت من من المذيبات المحمية اختيرت وهي النفثة الثقبمة والريفورميت ومزيج م الرمل بهيئة صخور وتم تمويثها مع وزن محدد من االسفمت. قيم النفاذية لهذه النماذج حسبت قبل وبعد المزج وبعد حقنها بالمذيبات المحضرة. كل قيم النفاذية تم تحويمها الى معدل التضرر الطبقي مقارنة مع النموذج غم من 22% عند مزج النموذج مع 22هرت حدوث تضرر طبقي بمعدل االصمي غير المموث. النتائج اض % بعد حقن الريفورميت والنفثة الثقيمة والخميط منهما , 12% , 11% , 12االسفمت. وهذا المعدل انخفض الى عمى التوالي. النفطية, الريفورمت, النفثة الثقيمة.: ترسب األسفمت, المذيبات المحمية العراقية, تضرر النفاذية, المكمامن الدالة الكممات