Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 4 2 2014 10 10 Forced Convection Heat Transfer of Giesekus Viscoelastic Fluid in Concentric Annulus with both Cylinders Rotation 1 9 398 10.22078/jpst.2014.398 EN Maryam Jouyandeh Chemical Engineering Department, Amirkabir University of Technology Mehdi Moayed Mohseni Department of Chemical Engineering, Amirkabir University of Technology Fariborz Rashidi Department of Chemical Engineering, Amirkabir University of Technology Journal Article 2012 08 05 A theoretical solution is presented for the forced convection heat transfer of a viscoelastic fluid obeying the Giesekus constitutive equation in a concentric annulus under steady state, laminar, and purely tangential flow. A relative rotational motion exists between the inner and the outer cylinders, which induces the flow. A constant temperature was set in both cylinders, in this study. The fluid properties are taken as constants and axial conduction is negligible, but the effect of viscous dissipation is included. The dimensionless temperature profile, the normalized bulk temperature, and the inner and outer Nusselt numbers are derived from solving non-dimensional energy equation as a function of all relevant non-dimensional parameters. The effects of Deborah number (De), mobility factor (α), Brinkman number (Br) and velocity ratio (β) on the normalized temperature profile and Nusselt number are investigated. The results indicate the significant effects of these parameters on the dimensionless temperature distribution and Nusselt number.

https://jpst.ripi.ir/article_398_b7b16ecf8ca53723593894116071700c.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 4 2 2014 10 10 AN IMPROVEMENT TO PHYSICAL PROPERTIES OF HEAVY-WEIGHT OIL WELL CEMENTS USING CARBON NANOTUBES 10 19 401 10.22078/jpst.2014.401 EN Ali Ghajari Author Hamid Soltanian Author Seyyed Alireza Mortazavi author Journal Article 2012 12 14 This study experimentally investigates the effect of multi-walled carbon nanotubes (MWNT’s), as a reinforcing material, on the physical properties of heavy-weight oil well cements. A candidate well is selected and the properties of the cement slurry used in a problematic section of the well are tested in the laboratory. Carbon nanotubes (CNT’s) are added as fibers to the cement slurry and the improvements in the cement slurry and stone properties are studied. This work discusses the problems associated with conventional heavy-weight oil well cement used in the candidate well and reports the detail of the improvements on cement properties obtained by adding CNT’s to cement slurry formulation. These properties include cement slurry rheological properties, free water, fluid loss, thickening time, cement stone elasticity, and compressive strength. When only 1 wt.% of CNT is added to the cement slurry, the yield point and plastic viscosity increase by eight and five times respectively, while the free water and fluid loss of cement slurry are reduced by 85% and 70% respectively. In addition, cement stone compressive strength increases by 73.8%. Moreover, the elastic properties of the cement stone are improved and higher values for the Young's modulus and Poisson's ratio are achieved; however, there is an optimum concentration of nano-additive at which the maximum yield point, plastic viscosity, compressive strength, Young's modulus, and Poisson's ratio are reached. The results of this study can be used to optimize the cement slurry design in any given set of conditions.

https://jpst.ripi.ir/article_401_816b112c6105b3ebd537828a39af4818.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 4 2 2014 10 10 CARBON DIOXIDE MINIMUM MISCIBILITY PRESSURE ESTIMATION (CASE STUDY) 20 27 397 10.22078/jpst.2014.397 EN Akram Vahidi IOR/EOR Research institute Mohammad Ahmadi nioc Alireza Nourmohammad eorresearch institute Journal Article 2013 09 09 Carbon dioxide flooding is considered to be one of the most effective enhanced oil recovery methods for the light oil reservoirs. Depending on the operating pressure, the process might be miscible or immiscible. Minimum miscibility pressure (MMP) is the most important parameter for assessing the applicability of any miscible gas flood for an oil reservoir. The miscibility condition is determined by conducting displacement tests at various pressures and the recovery is expected to improve as the displacement pressure increases, and then stays almost constant above the MMP. In this study, the MMP of pure carbon dioxide and an Iranian oil reservoir is estimated using slim-tube test. The experiment is performed under constant CO2 injection rate anddifferent displacement pressures above the bubble point pressure; input and output pressures are continually monitored during the test; the effluent liquid is flashed to atmospheric conditions and produced gases are passed through gas chromatography for compositional analysis. Volumetric oil recovery is measured, and oil recovery is plotted against the injection pressure at a 1.2 pore volume of the injected fluid. The results show that the oil recovery is more than 90% of original oil in place for all the pressures with a constant slope above the bubble point pressure. Therefore, MMP is considered to be equal to the bubble point pressure. In addition to the plot of oil recovery versus pressure, miscibility is also confirmed by the effluent gas composition, slim-tube pressure drop, and visual observations of phase behavior. The single phase high pressure fluid at the outlet of slim-tube, the small pressure drop across it, and no methane bank in the composition of effluent gas indicate that the miscibility is completely achieved. The experimental results are validated by modeling the test using a fully compositional simulator. The effect of varying CO2 mole fraction in the injected fluid is also investigated. The results show that an increase in CO2 mole fraction of the injected gas significantly decreases MMP.

https://jpst.ripi.ir/article_397_e46de7e1bcaaced9a54f1e9d0d2f800d.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 4 2 2014 10 10 A PARAMETRIC STUDY ON THE GROWTH OF SINGLE-WALLED CARBON NANOTUBES OVER CO-MO/MGO NANOCATALYST IN A FLUIDIZED BED REACTOR BY CCVD METHOD 28 34 394 10.22078/jpst.2014.394 EN Roghayyeh Lotfi Reseach institute of petroleum industry, RIPI Alimorad Rashidi Research Institute of Petroleum Industry (RIPI) Ehsaneh Fakhrmusavi Research Institute of Petroleum Industry (RIPI) Mahmood Fatemi RIPI Masoud Zare RIPI Maryam Rashtchi RIPI Journal Article 2013 07 17 Single-walled carbon nanotubes (SWNTs) with high yield and quality were synthesized using chemical vapor deposition (CVD) over Co-Mo/ MgO nanocatalyst in a fluidized bed reactor. Different parameters such as temperature, the ratio of hydrocarbon source to hydrogen, the flow rate of gas, growth time, the size of catalyst particles, heating rate, and the kind of hydrocarbon source were examined to assess their effects on the SWNT synthesis. The influence of these parameters on the carbon nanotubes yield and quality is also reported. Single-walled carbon nanotubes were characterized by using different characterization techniques including thermo-gravimetric analysis (TGA), scanning electron microscopy (SEM), tunneling electron microscopy (TEM), Raman spectroscopy, and X-ray diffraction (XRD). Under the optimum operation conditions (900 °C, 30 min, rate of gas=1800 ml/min, heating rate of 7 °C/min, size of catalyst particle=212 μm, volumetric ratio of hydrocarbon source to hydrogen=1:1), single-walled carbon nanotubes with an average diameter of 0.9 nm and a yield of 300% (related to the catalyst) were produced.

https://jpst.ripi.ir/article_394_28f0b864598a1291557bed248a998d4e.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 4 2 2014 10 10 RESEARCH ON CO2 FLOODING FOR IMPROVED OIL RECOVERY IN WATER FLOODING ABANDONED RESERVOIRS 35 42 402 10.22078/jpst.2014.402 EN Baolun Niu Production Engineering and Technology Institute, Zhongyuan Oilfield Branch Company, Sinopec, Puyang, Henan 457001, P R of China Ruijian Deng Zhongyuan Oilfield Branch Company, Sinopec, Puyang, Henan 457001, P R of China Yiqing Lin School of Foreign Languages, Xi'an Shiyou University, Xi'an, Shaanxi Province,710065, P. R. China Xinrong Wu Production Engineering and Technology Institute, Zhongyuan Oilfield Branch Company, Sinopec, Puyang, Henan 457001, P R of China Zhang Zhang Oil and Gas Development Company, Zhongyuan Petroleum Engineering Company, Sinopec, Puyang, Henan 457001, P R of China Changhua Yang Production Engineering and Technology Institute, Zhongyuan Oilfield Branch Company, Sinopec, Puyang, Henan 457001, P R of China Weidong Yang Production Engineering and Technology Institute, Zhongyuan Oilfield Branch Company, Sinopec, Puyang, Henan 457001, P R of China Zhaomin Li School of Petroleum Engineer, China University of Petroleum, Qingdao, Shandong Province, 266580, PR of China Shaoran Ren School of Petroleum, China University of Petroleum, Qingdao, Shandong province, 266580, PR of China Journal Article 2013 07 06 CO2 injection is an effective technique for improved oil recovery in light oil reservoirs, especially for water flooding abandoned reservoirs. In this study, the lower part of Es1 reservoirs in Pucheng oilfield was introduced as the target reservoir. By studying the minimum miscible pressure in CO2 flooding, the reservoir could achieve miscible flooding. Long core displacement experiments proved that water alternating CO2 flooding could significantly improve the recovery. For the reservoir characteristics, anti-corrosion technology in the process of injection was researched, and the H-20 inhibitor was screened. A channeling blocking agent in combination with the delayed expansion of gel particles and cross-linked copolymer was used to control the gas fluidity. The Pu 1-1 well groups were optimized to conduct a field trial. The cumulative injected liquid CO2 was 19219.95 ton, 0.248 PV and the cumulative increasing oil was 4520.9 t. The predicted recovery will increase by 8.3%. The successful implementation of the project can provide technical attempt for completion of energy to succeed and energy-saving emission reduction targets.

https://jpst.ripi.ir/article_402_69cb3ea317a32c4e6143e665fdb20b14.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 4 2 2014 10 10 APPLICATION OF ADAPTIVE NEURO FUZZY INFERENCE SYSTEM TO MODELING OXIDATIVE COUPLING OF METHANE REACTION AT ELEVATED PRESSURE 43 55 400 10.22078/jpst.2014.400 EN Maryam Sadi Research Institute of Petroleum Industry Jafar Sadeghzadeh Ahari Research Institute of Petroleum Industry Saeed Zarrinpashne Research Institute of Petroleum Industry Journal Article 2013 01 08 The oxidative coupling of methane (OCM) performance over Na-W-Mn/SiO2 at elevated pressures has been simulated by adaptive neuro fuzzy inference system (ANFIS) using reaction data gathered in an isothermal fixed bed microreactor. In the designed neuro fuzzy models, three important parameters such as methane to oxygen ratio, gas hourly space velocity (GHSV), and reaction temperature were considered as inputs and methane conversion and the selectivity of product hydrocarbons (C2+) were chosen as outputs. Two five-layer neuro fuzzy models based on the partitioning algorithm were designed at each reaction pressure to predict the product hydrocarbons (C2+) selectivity and methane conversion separately as a linear combination of inputs by the optimal selection of number and type of the membership functions. Moreover, to evaluate the ability and accuracy of the developed neuro fuzzy models in the prediction of OCM reaction performance, the results of ANFIS models were compared with experimental data and artificial neural network outputs. The comparison was carried out by the calculation of some statistical parameters such as correlation coefficient (R2), mean squared error (MSE), and average relative deviation (ARD). The results show that there are excellent agreement between model predictions and experimental data and the proposed ANFIS model can predict the methane conversion and product hydrocarbons (C2+) selectivity under different operating conditions by high accuracy.

https://jpst.ripi.ir/article_400_18d8042386b79e2c279fd162df0205c8.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 4 2 2014 10 10 THE EFFECT OF OILFIELD CHEMICALS ON THE SURFACE TENSION OF SURFACTANT SYSTEMS 56 66 399 10.22078/jpst.2014.399 EN Mohammad Saber Karambeigi School of Chemical, Gas and Petroleum Engineering, Semnan University Ali Haghighi Asl School of Chemical, Gas and Petroleum Engineering, Semnan University Masoud Nasiri School of Chemical, Gas and Petroleum Engineering, Semnan University Journal Article 2013 11 25 Treated sea water is the most significant source of water and surfactant floods. The various chemicals employed in treatment plants should be compatible with surfactant systems. Based on surface tension experiments, the activity of these chemicals is examined over a wide range of concentrations in different solutions, including distillated water, sea water by using three types of surfactant mixtures. For this purpose, the conventional chemicals of a typical water treatment plant, namely scale inhibitor, corrosion inhibitor, biocide, O2 scavenger, coagulant, and antifoam, were selected. The results show chemicals are completely compatible with the surfactant systems in concentrations utilized for an oilfield dosage. Scale inhibitor, O2 scavenger, and coagulant did not show any surface properties, but the positive effects of the other chemicals on the reduction of the surface tension were observed. The interaction of active chemicals was evaluated using response surface methodology. The results demonstrate that antifoam had more significant effects on the reduction of the surface tension than corrosion inhibitor and biocide.

https://jpst.ripi.ir/article_399_352fe25daf686bdb4edca223c921acea.pdf

Research Institute of Petroleum Industry (RIPI) Journal of Petroleum Science and Technology 2251-659X 4 2 2014 10 10 MICROFACIES, DEPOSITIONAL ENVIRONMENT, AND DIAGENETIC PROCESSES OF THE MAUDDUD MEMBER, IN THE PERSIAN GULF 67 78 396 10.22078/jpst.2014.396 EN Alireza Shakeri Head of Petrolum Geology Research Center Somayeh Parham PhD Candidate of Hormozgan University-Senior Reservoir Geologist Journal Article 2013 07 22 Mauddud member with the age of late Albian to Cenomanian is equivalent to the lower Sarvak formation in the southern Persian Gulf and adjacent area. In this work, microfacies, depositional environment, and diagenetic processes affected the Mauddud member in a field in the Persian Gulf are investigated. Based on the studies of available cores and thin sections of 3 wells, five types of microfacies, namely MF1 to MF5, have been identified in the Mauddud member. These microfacies have been deposited in 2 facies belt including a vast lagoon and local bioclastic shoal. Based on the lack of great barrier reefs and calciturbidities and gradual change of microfacies into each other, it is concluded that the Mauddud member was deposited on a shallow marine homoclinal ramp. Several diagenetic processes such as bioturbation, micritization, dissolution, cementation, dolomitizetion, and compaction have influenced this member. Among all, dissolution increased porosity and thereby reservoir quality, while cementation and compaction decreased reservoir characteristics. Finally, it was found out that matrix porosity was the main type of porosity in the studied interval.

https://jpst.ripi.ir/article_396_f8c1f23d6a8d8d7904fc0ea8e066b3bb.pdf