Polymeric surfactants as alternative to improve waterflooding oil recovery efficiency

Chemical formulations, including surfactants, polymers, alkalis, or their combinations, are widely used in different oil recovery processes to improve water injection performance. However, based on challenging profit margins in most mature waterfloods in Colombia and overseas, it is necessary to explore alternatives that could offer better performance and greater operational flexibility than the conventional technologies used for enhanced oil recovery (EOR) processes. Polymeric surfactants are compounds widely used in the manufacture of domestic and industrial cleaning, pharmaceutical, cosmetic, and food products. These compounds represent an interesting alternative as they can simultaneously increase the viscosity in water solution and reduce the interfacial tension (IFT) in the water/oil system, which would increase the efficiency of EOR processes. This article shows a methodological evaluation through laboratory studies, numerical reservoir simulation, and conceptual engineering design to apply polymeric surfactants (Block Copolymer Polymeric Surfactants or BCPS) as additives to improve efficiency in water injection processes. Block copolymer type products of ethylene oxide (EO) - propylene oxide (PO) - ethylene oxide (EO) in aqueous solution were studied to determine their rheological and surfactant behavior under the operating conditions of a Colombian field. In the conditions studied, these products allow to reduce the interfacial tension up to 2x10-1 mN/m values and also cause a shear-thinning rheological behavior following the power law at very low shear rates (0.1 s-1– 1 s-1), which corresponds to an increase up to four orders of magnitude in the capillary number (Nc). The IFT and the viscosity reached are maintained in wide ranges of salinity, BCPS concentration, and shear rates, making it a robust performance formulation. In a model porous medium, BCPS tested have moderate adsorption, less than conventional surfactants but higher than HPAM polymers, in any way allowing a favorable wettability condition. Additionally, it was observed that they offer a resistance factor up to 16 times, causing greater displacement efficiency than water injection, allowing better sweeping in low permeability areas without injectivity restrictions. Numerical simulation shows that it is possible to reach incremental production up to 238,5 TBO by injecting a continuous slug of 0.15 pore volumes of BCPS and HPAM, each with 2,000 ppm concentration and a flow rate of 2,500 BPD. As BCPS are simple handling and dilution products, these could be injected directly in water injection flow using a high precision dosing pump with high pressure and flow rate operational variables.

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Influence of New SiO2 Nanofluids on Surface Wettability and Interfacial Tension Behaviour between Oil-Water Interface in EOR Processes

Journal of Nano Research ◽

10.4028/www.scientific.net/jnanor.26.1 ◽

2013 ◽

Vol 26 ◽

pp. 1-8 ◽

Cited By ~ 13

Author(s):

A. Amraei ◽

Zahra Fakhroueian ◽

Alireza Bahramian

Keyword(s):

Surface Tension ◽

Interfacial Tension ◽

Oil Recovery ◽

Ph Value ◽

Pure Water ◽

Contact Angles ◽

Carbonate Reservoir ◽

Reservoir Rock ◽

Water Interface ◽

Eor Processes

Fine SiO2 nanosphericals (2-5nm) and new various stable nanofluids including Tween 80, Span 80, Lauric alcohol-3EO, CTAB, SDS and K-Laurate surfactants in water or paraffin based solution were used as new SiO2 nanoproducts in oil recovery. These nanofluids can strongly change oil-wet carbonate reservoir rock to complete water-wet wettability and showed an excellent trend of surface tension (S.T) and IFT (interfacial tension) reduction in comparison with pure water and reference solutions. The CaCO3 plates reservoir was then aged for 2, 5 and 8 days into the 1, 3 and 8% of different concentrations of synthesized SiO2 nanofluids (effect of various concentrations via different aging time). Air/water and n-decane/water contact angles on oil-wet and clean carbonate rock aged in designed SiO2 nanofluids were measured and the pH value as a significant factor estimated. The interesting influence of microwave irradiation on surface tension and IFT including various SiO2 nanofluids was investigated after 12 min which some of the especial nanofluid concentrations showed successful reduction. Our findings indicated the important effect of temperature over decreasing of surface tension and IFT between oil and water interface including SiO2 nanofluids after annealing at 70°C. Therefore, this phenomenon can be significantly capable and valuable in applying of new technology in the fabrication of novel nanofluids in EOR processes and saving source of energy regarding to conventional production.

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Low Salinity Hot Water Injection With Addition of Nanoparticles for Enhancing Heavy Oil Recovery

Journal of Energy Resources Technology ◽

10.1115/1.4042238 ◽

2019 ◽

Vol 141 (7) ◽

Cited By ~ 8

Author(s):

Yanan Ding ◽

Sixu Zheng ◽

Xiaoyan Meng ◽

Daoyong Yang

Keyword(s):

Thermal Energy ◽

Oil Recovery ◽

Heavy Oil ◽

Water Injection ◽

Operating Conditions ◽

Hot Water ◽

Wettability Alteration ◽

Heavy Oil Recovery ◽

Oil Saturation ◽

Low Salinity

In this study, a novel technique of low salinity hot water (LSHW) injection with addition of nanoparticles has been developed to examine the synergistic effects of thermal energy, low salinity water (LSW) flooding, and nanoparticles for enhancing heavy oil recovery, while optimizing the operating parameters for such a hybrid enhanced oil recovery (EOR) method. Experimentally, one-dimensional displacement experiments under different temperatures (17 °C, 45 °C, and 70 °C) and pressures (about 2000–4700 kPa) have been performed, while two types of nanoparticles (i.e., SiO2 and Al2O3) are, respectively, examined as the additive in the LSW. The performance of LSW injection with and without nanoparticles at various temperatures is evaluated, allowing optimization of the timing to initiate LSW injection. The corresponding initial oil saturation, production rate, water cut, ultimate oil recovery, and residual oil saturation profile after each flooding process are continuously monitored and measured under various operating conditions. Compared to conventional water injection, the LSW injection is found to effectively improve heavy oil recovery by 2.4–7.2% as an EOR technique in the presence of nanoparticles. Also, the addition of nanoparticles into the LSHW can promote synergistic effect of thermal energy, wettability alteration, and reduction of interfacial tension (IFT), which improves displacement efficiency and thus enhances oil recovery. It has been experimentally demonstrated that such LSHW injection with the addition of nanoparticles can be optimized to greatly improve oil recovery up to 40.2% in heavy oil reservoirs with low energy consumption. Theoretically, numerical simulation for the different flooding scenarios has been performed to capture the underlying recovery mechanisms by history matching the experimental measurements. It is observed from the tuned relative permeability curves that both LSW and the addition of nanoparticles in LSW are capable of altering the sand surface to more water wet, which confirms wettability alteration as an important EOR mechanism for the application of LSW and nanoparticles in heavy oil recovery in addition to IFT reduction.

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Effect of ionic strength in low salinity water injection processes

CT&F - Ciencia Tecnología y Futuro ◽

10.29047/01225383.269 ◽

2020 ◽

Vol 10 (2) ◽

pp. 17-26

Author(s):

Gustavo Maya Toro ◽

Luisana Cardona Rojas ◽

Mayra Fernanda Rueda Pelayo ◽

Farid B. Cortes Correa

Keyword(s):

Ionic Strength ◽

Interfacial Tension ◽

Crude Oil ◽

Oil Recovery ◽

Water Injection ◽

Spontaneous Imbibition ◽

Low Salinity ◽

Low Salinity Water ◽

Salinity Water ◽

Low Salinity Water Injection

Low salinity water injection has been frequently studied as an enhanced oil recovery process (EOR), mainly due to promising experimental results and because operational needs are not very different from those of the conventional water injection. However, there is no agreement on the mechanisms involved in increasing the displacement of crude oil, except for the effects of wettability changes. Water injection is the oil recovery method mostly used, and considering the characteristics of Colombian oil fields, this study analyses the effect of modifying the ionic composition of the waters involved in the process, starting from the concept of ionic strength (IS) in sandstone type rocks. The experimental plan for this research includes the evaluation of spontaneous imbibition (SI), contact angles, and displacement efficiencies in Berea core plugs. Interfacial tension and pH measurements were also carried out. The initial scenario consists in formation water (FW), with a total concentration of 9,800 ppm (TDS) (IS ~ 0.17) and a 27 °API crude oil. Magnesium and Calcium brine were also used in a first approach to assess the effect of the divalent ions. Displacement efficiency tests are performed using IS of 0.17, 0.08, and 0.05, as secondary and tertiary oil recovery and the recovery of oil increases in both scenarios. Spontaneous imbibition curves and contact angle measurements show variations as a function of the ionic strength, validating the displacement efficiencies. Interfacial tension and pH collected data evidence that fluid/fluid interactions occur due to ionic strength modifications. However, as per the conditions of this research, fluid/fluid mechanisms are not as determining as fluid/rock.

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The use of laurylamine hydrocholoride CH3(CH2)11 NH3 –Cl for secondary oil recovery

Baghdad Science Journal ◽

10.21123/bsj.9.1.120-123 ◽

2012 ◽

Vol 9 (1) ◽

pp. 120-123

Author(s):

Baghdad Science Journal

Keyword(s):

Interfacial Tension ◽

Oil Recovery ◽

Cationic Surfactants ◽

Water Injection ◽

Solution Concentration ◽

Oil Field ◽

Residual Oil ◽

Secondary Oil Recovery ◽

Total Oil ◽

The Relationship

Laurylamine hydrochloride CH3(CH2)11 NH3 – Cl has been chosen from cationic surfactants to produce secondary oil using lab. model shown in fig. (1). The relationship between interfacial tension and (temperature, salinity and solution concentration) have been studied as shown in fig. (2, 3, 4) respectively. The optimum values of these three variables are taken (those values that give the lowest interfacial tension). Saturation, permeability and porosity are measured in the lab. The primary oil recovery was displaced by water injection until no more oil can be obtained, then laurylamine chloride is injected as a secondary oil recovery. The total oil recovery is 96.6% or 88.8% of the residual oil has been recovered by this technique as shown in fig. (5). This method was applied in an oil field and it gave approximate values close to that obtained in the lab.

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The Role of Emulsification and Interfacial Tension Ift For the Enhanced Oil Recovery Eor in Surfactant Flooding

10.2118/206432-ms ◽

2021 ◽

Author(s):

Xiaoxiao Li ◽

Xiang'an Yue ◽

Jirui Zou ◽

Lijuan Zhang ◽

Kang Tang

Keyword(s):

Interfacial Tension ◽

Crude Oil ◽

Flow Rate ◽

Oil Recovery ◽

Surfactant Flooding ◽

Displacement Efficiency ◽

Oil Viscosity ◽

Oil Film ◽

Oil Flow ◽

Emulsifying Capacity

Abstract In this study, a visualized physical model of artificial oil film was firstly designed to investigate the oil film displacement mechanisms. Numerous comparative experiments were conducted to explore the detachment mechanisms of oil film and oil recovery performances in different fluid mediums with flow rate. In addition, the of influencing factors of oil film were comprehensively evaluated, which mainly includes: flow rate, surfactant behaviors, and crude oil viscosity. The results show that, (1) regardless of the viscosity of crude oil, flow rate presents a limited contribution to the detachment of oil film and the maximum of ultimate oil film displacement efficiency is only approximately 10%; (2) surfactant flooding has a synergistic effect on the oil film displacement on two aspects of interfacial tension (ITF) reduction and emulsifying capacity. Giving the most outstanding performance for two oil samples in all runs, IFT reduction of ultra-low value is not the only decisive factor affecting oil film displacement efficiency, but the emulsifying capability plays the key role to the detachment of oil film due to effect of emulsifying and dispersing on oil film; (3) the increasing flow rate of surfactant flooding is able to enhance the detachment of oil film but has an objective effect on the final oil film displacement efficiency; (4) flow rate have the much influence on the detachment of oil film, but the most easily controlled factor is the surfactant property. The finding provides basis for oil film detachment and surfactant selection EOR application.

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Optimal Design of Progressing Cavity Pumps(PCP)

Journal of Energy Resources Technology ◽

10.1115/1.2358142 ◽

2006 ◽

Vol 128 (4) ◽

pp. 275-279 ◽

Cited By ~ 7

Author(s):

G. Robello Samuel ◽

Ken J. Saveth

Keyword(s):

Optimal Design ◽

Flow Rate ◽

Oil Recovery ◽

High Efficiency ◽

Maximum Flow ◽

Operating Conditions ◽

Window Of Opportunity ◽

Trial And Error ◽

Artificial Lift ◽

Energy Independence

The drive for energy independence has created a window of opportunity for innovations in oil recovery. New artificial lift methods like progressing cavity pumping have been successfully applied to downhole pumping applications. The multilobe pumps are also making inroads into the industry to be used under different operating conditions. Although the design has been mainly based on empirical standards and trial and error modifications, a more phenomenally optimum design of the pump is required to achieve a high efficiency standard. The optimal relationship between the pitch and the diameter of the housing is obtained to achieve a maximum flow rate for multilobe pumps.

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Experimental study of the performances of commercial surfactants in reducing interfacial tension and wettability alteration in the process of chemical water injection into carbonate reservoirs

Journal of Petroleum Exploration and Production Technology ◽

10.1007/s13202-019-00789-0 ◽

2019 ◽

Vol 10 (4) ◽

pp. 1551-1563 ◽

Cited By ~ 5

Author(s):

Siamak Najimi ◽

Iman Nowrouzi ◽

Abbas Khaksar Manshad ◽

Amir H. Mohammadi

Keyword(s):

Contact Angle ◽

Interfacial Tension ◽

Oil Recovery ◽

Saline Water ◽

Water Injection ◽

Reservoir Rock ◽

Water Flooding ◽

Wettability Alteration ◽

Core Flooding ◽

Chemical Water

Abstract Surfactants are used in the process of chemical water injection to reduce interfacial tension of water and oil and consequently decrease the capillary pressure in the reservoir. However, other mechanisms such as altering the wettability of the reservoir rock, creating foam and forming a stable emulsion are also other mechanisms of the surfactants flooding. In this study, the effects of three commercially available surfactants, namely AN-120, NX-1510 and TR-880, in different concentrations on interfacial tension of water and oil, the wettability of the reservoir rock and, ultimately, the increase in oil recovery based on pendant drop experiments, contact angle and carbonate core flooding have been investigated. The effects of concentration, temperature, pressure and salinity on the performances of these surfactants have also been shown. The results, in addition to confirming the capability of the surfactants to reduce interfacial tension and altering the wettability to hydrophilicity, show that the TR-880 has the better ability to reduce interfacial tension than AN-120 and NX-1510, and in the alteration of wettability the smallest contact angle was obtained by dissolving 1000 ppm of surfactant NX-1510. Also, the results of interfacial tension tests confirm the better performances of these surfactants in formation salinity and high salinity. Additionally, a total of 72% recovery was achieved with a secondary saline water flooding and flooding with a 1000 ppm of TR-880 surfactant.

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Effects of interfacial tension on formation of poly(ethylene oxide)-block-polystyrene micelles from emulsions

RSC Advances ◽

10.1039/c4ra14157a ◽

2015 ◽

Vol 5 (6) ◽

pp. 4350-4354 ◽

Cited By ~ 6

Author(s):

Mei Su ◽

Lulu Wang ◽

Guangyu Zhang ◽

Yan Huang ◽

Zhaohui Su

Keyword(s):

Block Copolymer ◽

Ethylene Oxide ◽

Interfacial Tension ◽

Solvent Evaporation ◽

Amphiphilic Block Copolymer ◽

Solvent Evaporation Method ◽

Evaporation Method ◽

Poly Ethylene Oxide ◽

Poly Ethylene

In this report, we show that the structure of an amphiphilic block copolymer assembled through the emulsion and solvent evaporation method can be regulated by tuning the interfacial tension with a third solvent.

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Effect of Salts on Interfacial Tension and CO2 Mass Transfer in Carbonated Water Injection

Energies ◽

10.3390/en12040748 ◽

2019 ◽

Vol 12 (4) ◽

pp. 748 ◽

Cited By ~ 6

Author(s):

Aly Hamouda ◽

Nikhil Bagalkot

Keyword(s):

Mass Transfer ◽

Interfacial Tension ◽

Oil Recovery ◽

Hydration Shell ◽

Water Injection ◽

Oh Groups ◽

Carbonated Water Injection ◽

Carbonated Water ◽

Co2 Mass Transfer ◽

The Impact

Carbonated water injection (CWI) is a promising enhanced oil recovery (EOR) and CO2 sequestration method, which overcomes the problems associated with CO2 EOR. CO2 mass transfer and interfacial tension (IFT) are important parameters that influence oil recovery efficiency. This study addresses the impact of MgCl2 and Na2SO4 in carbonated water (CW) on CW/hydrocarbon IFT and CO2 mass transfer. An axisymmetric drop shape analysis was used to estimate the IFT and the CO2 diffusion coefficient. It was found that CW+MgCl2 reduced both the CW/n-decane IFT (36.5%) and CO2 mass transfer, while CW+Na2SO4 increased both the IFT and CO2 mass transfer (57%). It is suggested that reduction in IFT for CW+MgCl2 brine is mainly due to the higher hydration energy of Mg2+. The Mg2+ ion forms a tight bond to the first hydration shell [Mg(H2O)6]2+, this increases the effective size at the interface, hence reduce IFT. Meanwhile, the SO42− outer hydration shell has free OH groups, which may locally promote CO2 mass transfer. The study illustrates the potential of combining salts and CW in enhancing CO2 mass transfer that can be the base for further investigations. Furthermore, the contribution and proposed mechanisms of the different ions (SO42− and Mg2+) to the physical process in carbonated water/hydrocarbon have been addressed, which forms one of primary bases of EOR.

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