共查询到10条相似文献,搜索用时 78 毫秒
1.
Polymer flooding characteristics of partially hydrolyzed polyacrylamide (HPAM) solution with the addition of NaOH were examined in homogeneous glass‐bead packs. The heavy oil recovery in unconsolidated sandstone formations by applying the alkali‐polymer flooding was observed. Experimental results showed that HPAM solution was sensitive to temperature, salinity, and alkali, finding that alkali‐polymer solutions are more effective in improving viscosity than conventional polymer solutions. The solution of 0.5 wt % NaOH mixed with 1500 ppm HPAM (12 mol % hydrolysis degree) was found to be the optimal choice, which gives rise to the highest viscosity on the rheological characterization. Flood tests using the alkali‐polymer solution showed an increase in oil recovery by 30% over water‐flooding when the water‐cut reached 95%, indicating that alkali‐polymer could be more effective in improving sweep efficiency than polymer flood. © 2012 Wiley Periodicals, Inc. J. Appl. Polym. Sci., 2013 相似文献
2.
3.
Jamal Aalaie Khosrow Jarrahian Saeed Ghorashi Vali Ahmad Sajjadian 《Iranian Polymer Journal》2014,23(11):827-834
Four polymeric solutions based on xanthan, high and low molecular weight sulfonated polyacrylamides, and hydrolyzed polyacrylamide were prepared in aqueous solutions and their behaviors in enhanced oil recovery applications were investigated. The effect of thermal aging on polymer solutions was evaluated through rheological measurement. Pendant drop method was also used for measuring the interfacial tension (IFT) between crude oil and brine containing different polymer solutions. Moreover, the zeta potential of the oil reservoir particles treated with oil and polymer was determined by electrophoresis method in a nano-zeta meter instrument. In addition, sand pack and core flooding setup were used for evaluating the effectiveness of the polymer solutions in porous media. Polymer solutions displayed non-Newtonian behavior in almost the whole range of the shear rate applied; a shear thinning behavior was seen. Furthermore, the aging of polymers in formation water decreased the shear viscosity of all the polymers. The oil/water IFT decreased by the addition of polymers to water. The effect of xanthan polymer on zeta potential value was greater than that of the three acrylamide-based polymers. According to sand pack tests, by increasing the polymer concentration, the incremental oil recovery initially increased up to a polymer concentration of 3,500 ppm and then started to fall. Recovery factor increased from 50 to 65 % using the polymer solution in core flooding experiments. By increasing the injection rate from 0.2 to 3 mL/min, the injected fluid had less time to sweep the pores and consequently the amount of recovered oil decreased. 相似文献
4.
5.
F. M. Orr Jr. J. P. Heller J. J. Taber 《Journal of the American Oil Chemists' Society》1982,59(10):810A-817A
Of the enhanced oil recovery methods currently being considered for application to many of the nation’s older oil fields,
carbon dioxide flooding may offer the largest potential for additional oil recovery. The physical mechanisms by which CO2 contacts and mobilizes crude oil are reviewed. Influence on the displacement process of factors such as the phase behavior
of CO2-crude oil mixtures, swelling of oil by dissolved CO2, and reduction of oil viscosity are considered. Adverse effects of the viscous instability which occurs when very low viscosity
CO2 displaces the more viscous oil and water are dicussed. Advantages and disadvantages of three potential methods for controlling
the mobility of CO2 are reviewed: thickening CO2 with polymeric additives, reduction of CO2 mobility by high water saturations, and use of surfactants to generate foam-like emulsions of water and CO2. Field experience to date and the recent surge in field activity are discussed. Finally, a brief assessment of the future
of CO2 flooding research and practice is offered. 相似文献
6.
综述了国内外三次采油用五大类驱油耐温抗盐水溶性聚合物的研究现状,提出一种提高聚丙烯酰胺类聚合物耐温抗盐性能的的新方法:即开发一种廉价高效二价金属离子络合剂。分析了二价金属离子络合剂的作用机理,并明确了以后的研究方向。 相似文献
7.
《Journal of Industrial and Engineering Chemistry》2014,20(1):228-233
Surfactant-enhanced oil recovery is a type of enhanced oil recovery (EOR), a method to produce residual oil by injecting surfactant solution into the reservoir. The application of surfactant EOR requires knowledge of the phase behavior for more efficient production of residual oil.In this study, the relationship between dodecyl alkyl sulfate and some specific crude oils was examined through phase behavior test. It was found that the branched surfactant was more effective than the linear surfactant. The system was stable at salinities <3 wt%. On adding a small amount of co-surfactant, the emulsion activity was increased.The gravity drainage flooding test (GDFT) was performed to determine the potential of dodecyl alkyl sulfate to produce residual oil in porous media. It was found that the solution could be flooded at temperatures of 60 °C or higher. In the core flooding test, injecting one pore volume of 2 wt% surfactant solution with 3 wt% salinity produced 26.6% more oil after water flood. With the addition of only 0.01 wt% co-surfactant, oil production increased by 1.6%. Contrary to the phase behavior test, the linear surfactant produced 1.3% more oil than the branched surfactant in the core flooding test. 相似文献
8.
9.
Ahmad Akanbi Adewunmi Suzylawati Ismail Abdullah Saad Sultan Zulkifli Ahmad 《Korean Journal of Chemical Engineering》2017,34(6):1638-1650
The complexity of well and reservoir conditions demands frequent redesigning of water plugging polymer gels during enhanced oil recovery (EOR). In the present study, we developed coal fly ash (CFA) based gels from polyacrylamide (PAM) polymer and polyethyleneimine (PEI) crosslinker for water control in mature oil fields. The CFA acts as an inorganic additive to fine-tune gelation performance and rheological properties of PAM/PEI gel system. Hence, effects of various CFA (0.5 to 2 wt%), PAM (2 to 8.47 wt%) and PEI (0.3 to 1.04 wt%) concentrations on gelation kinetics and dynamic rheology of pure PAM/PEI gel and PAM/PEI-CFA composite gels were studied at a representative reservoir temperature of 90 oC. Experimental results reveal that gelation time of pure PAM/PEI gel increases with increasing CFA addition. Further observation demonstrates that increasing PAM and PEI concentrations decreases the gelation times of PAM/PEI-CFA composite gels. Gelation time was found to be within 3-120 hours. Understanding the property of reaction order enables better prediction of gelation time. Dynamic rheological data show that viscoelastic moduli (G′ and G″) of various PAM/PEI-CFA composite gels improved better as compared to the pure PAM/PEI gel across the strain-sweep and frequency-sweep tests. SEM analysis of selected samples at 72 hours and 720 hours of gelation activity consolidated gelation kinetics and dynamic rheological results. These polymer gels are excellent candidates for sealing water thief zones in oil and gas reservoirs. 相似文献
10.
Polyacrylamides can be readily characterized using techniques such as IR spectroscopy, 13C-NMR, elementary analysis, TGA, and x-ray diffraction. The first three techniques can also be used quantitatively to measure the degree of hydrolysis of the polymers, without the need to know accurately the weight of the sample. The presence of inorganic salts, such as Na2SO4, Na4(CO3)SO4, and Na2CO3, is readily detected via IR or wide-angle x-ray diffraction. No evidence of crystallinity is found in the samples studied. 相似文献