Critical review of alkaline-polymer flooding

Sheng, James J.

doi:10.1007/s13202-016-0239-5

Cited by 55 publications

(36 citation statements)

References 27 publications

Supporting

Mentioning

Contrasting

Unclassified

Order By: Relevance

“…The temperature of liquid 2 and the flowing parameters for liquids 1 and 2 are calculated. (8). The hydraulic friction, hydraulic pressure drop for liquids 1 and 2, and other concerned parameters at the calculated unit are calculated.…”

Section: Solution Methodsmentioning

confidence: 99%

“…In Daqing oil field, which is the largest oil field in China, polymer flooding has contributed to more than 10 % of enhanced oil recovery [4,5], and over ten million tons of crude oil has been produced every year by polymer flooding [6,7]. Nowadays, alkali-surfactant-polymer (ASP) combinational flooding system has become a promising direction of EOR technology [8][9][10]. It was proved that the ASP flooding has improved oil recovery by 17.2% and recovery increment of SP flooding can reach 14.3% [11].…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Viscosity Loss and Hydraulic Pressure Drop on Multilayer Separate Polymer Injection in Concentric Dual-Tubing

et al. 2020

View full text Add to dashboard Cite

Multilayer separate polymer injection in concentric dual-tubing is a special method for enhancing oil recovery in later development stage of the multilayer formation. During the injection process, heat exchange occurs among the inner tubing, tubing annulus and formation, making the thermal transfer process more complicated than traditional one. This work focuses on the polymer flowing characteristics during the multilayer separate polymer flooding injection process in the wellbore. A temperature–viscosity numerical model is derived to investigate the influencing factors on polymer dual-tubing injection process. Then, an estimate-correct method is introduced to derive the numerical solutions. Several influences have been discussed, including the axial temperature distribution, viscosity distribution, pressure drop, and flow pattern of polymer. Results show that under low injecting rates, below 5 m3/d, formation temperature will greatly decrease the polymer viscosity. When the injecting rates above 20 m3/d, the polymer just decreases 1–3 mPa·s at the bottom of well, which is really small. Additionally, the temperature distribution, the coefficient of friction under different injecting rates have been discussed. Generally, this method provides a new way to analyze thermal conductivity during the polymer injection process which is meaningful for polymer flooding in the oilfield application.

show abstract

Section: Solution Methodsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Viscosity Loss and Hydraulic Pressure Drop on Multilayer Separate Polymer Injection in Concentric Dual-Tubing

et al. 2020

View full text Add to dashboard Cite

show abstract

“…Simultaneous injection of polymer slug with alkali improves mobility control of injectant and complement the efficiency of alkali flooding. Also, the presence of alkali lowers the adsorption of polymer on rock pores [100]. However, an optimum concentration of alkali and polymer required for formulation of AP slug must be determined.…”

Section: Alkali-polymer (Ap) Floodingmentioning

confidence: 99%

“…Besides, there is competition for adsorption of both chemicals on rock pores which ultimately results in lower adsorption of the surfactant. An additional mechanism of this EOR process is the synergy between the injected synthetic surfactant and the in situ generated soap caused by the presence of alkali [100,105]. The optimum salinity for the generated soap is very low.…”

Section: Alkali-surfactant-polymer (Asp) Floodingmentioning

confidence: 99%

An overview of chemical enhanced oil recovery: recent advances and prospects

et al. 2019

View full text Add to dashboard Cite

Despite the progress made on renewable energy, oil and gas remains the world's primary energy source. Meanwhile, large amounts of oil deposits remain unrecovered after application of traditional oil recovery methods. Chemical enhanced oil recovery (EOR) has been adjudged as an efficient oil recovery technique to recover bypassed oil and residual oil trapped in the reservoir. This EOR method relies on the injection of chemicals to boost oil recovery. In this overview, an up-to-date synopsis of chemical EOR with detailed explanation of the chemicals used, and the mechanism governing their oil recovery application have been discussed. Challenges encountered in the application of the various conventional chemical EOR methods were highlighted, and solutions to overcome the challenges were proffered. Besides, the recent trend of incorporating nanotechnology and their synergistic effects on conventional chemicals stability and efficiency for EOR were also explored and analysed. Finally, laboratory results and field projects were outlined. The review of experimental studies shows that porescale mechanisms of conventional chemical EOR is enhanced by incorporating nanotechnology, hence, resulted in higher efficiency. Moreover, the use of ionic liquid chemicals and novel alkaline-cosolvent-polymer technology shows good potentials. This overview presents an extensive information about chemical EOR applications for sustainable energy production.

show abstract

“…The complex nature of carbonate reservoirs as well as their high formation water salinity and high temperature (~ 170,000 ppm and ~ 120 °C), especially in the Middle Eastern region, makes it difficult to find suitable polymer candidates to implement this IOR technique. In addition, performance of polymer flooding is majorly dependent on reservoir heterogeneity, salinity, temperature, permeability and its compatibility with other chemicals use for oil recovery (Almansour et al 2017;Hashmet et al 2017a;Sheng 2017).…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation of polymer flooding with low-salinity preconditioning of high temperature–high-salinity carbonate reservoir

Alfazazi

Alameri

Hashmet

2018

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

Application of polymer flooding in high temperature-high salinity (HTHS) carbonate reservoirs is challenging due to lack of polymers that can withstand such harsh reservoir conditions. The traditional polymers are usually sensitive to high salinity, especially at high temperature. However, injection of low-salinity make-up brines may precondition high-salinity reservoirs before initiating polymer flooding which may reduce chemical degradation of polymer. This study aims to evaluate the effectiveness of a partially hydrolyzed polyacrylamide base polymer for mobility control application in a low-salinity preconditioned carbonate reservoir and hence on the improvement of oil recovery at HTHS carbonate reservoir. Core flooding experiments using unsteady-state technique were conducted on reservoir cores with permeability range of 10-100 mD. During each experiments, salinity of the make-up brines were changed to study the effect of preflush salinity and polymer flooding in HTHS reservoir. Oil production from water flooding for all the cases was found to be between 49 and 65%. Polymer helped to reduce the mobility ratio from 4.1 to less than 1 and additional 7-11% of oil was recovered from the remaining oil saturation after water flooding. Comparisons were also made between oil recovery results based on volumetric production and in situ saturation monitoring (ISSM) data, which were found to be matching. Additionally, the ISSM helped to understand the performances of fluids injected during oil recovery stages and captured front movement of the fluids at all time. Also, high capillary end effect was confirmed from the ISSM which may lead to underestimation of the oil recovery from water flooding in the absence of ISSM. Resistance factor and residual resistance factor were also calculated during all core flooding experiments and were found to be 7.0, 2.4, 36 and 3.7, 1.4, 8.9, respectively.

show abstract

Critical review of alkaline-polymer flooding

Cited by 55 publications

References 27 publications

Viscosity Loss and Hydraulic Pressure Drop on Multilayer Separate Polymer Injection in Concentric Dual-Tubing

Viscosity Loss and Hydraulic Pressure Drop on Multilayer Separate Polymer Injection in Concentric Dual-Tubing

An overview of chemical enhanced oil recovery: recent advances and prospects

Experimental investigation of polymer flooding with low-salinity preconditioning of high temperature–high-salinity carbonate reservoir

Contact Info

Product

Resources

About