A review of crude oil emulsification and multiphase flows in chemical flooding

Yazhou, Zhou; Yin, Daiyin; Li, Yuanting; He, Jingang; Zhang, Chengli

doi:10.1002/ese3.1351

Cited by 6 publications

(3 citation statements)

References 136 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The ability of ASP flooding to reduce the remaining oil in a bound state is stronger than that of high-concentration polymer, with a reduction of 2.8%. ASP flooding has a significant effect on the remaining oil on the pore surface, sheet film, and adsorption-like particles. − …”

Section: Resultsmentioning

confidence: 99%

Microscopic Remaining Oil Distribution Regularity and Enhanced Oil Recovery Methods after Polymer Flooding

Chen,

Cao,

Jiang

et al. 2024

Energy Fuels

View full text Add to dashboard Cite

In this article, the testing data of the coring wells was analyzed to statistically summarize the variable regularity of reservoir physical parameters after polymer flooding. The laser confocal method was used to study the microscopic remaining oil distribution regularity in natural cores, and the effects of different pore structures and permeability levels on the remaining oil distribution were quantified. Both natural and artificial cores were used to compare and analyze the differences in displacement efficiency and microscopic remaining oil exploitation between different chemical flooding methods after polymer flooding. Additionally, microscopic visualization models were used to study the activation and coalescence mechanism of the remaining oil. The results showed that the permeability, washed thickness, and displacement efficiency of the reservoir after polymer flooding were significantly higher than before. After polymer flooding, the distribution characterization of the remaining oil was highly dispersed and locally enriched, and some free-state oil remained available in medium and high permeability reservoirs. The largest amount of remaining oil distribution was observed in the thinner throat reservoirs. Reservoirs with sorting coefficients of 4–6 mainly existed bound state oil. Laboratory displacement experiment results showed that ASP flooding with a higher viscosity ratio and capillary number exhibited a better oil displacement effect; the final recovery of ASP was 4.9% higher than that of a high-concentration polymer. Furthermore, ASP flooding demonstrated a stronger reduction in bound state oil compared with high-concentration polymer flooding, with an increase of 2.8%. The ASP system activates and coalesces the microscopic remaining oil after polymer flooding by high viscoelasticity, ultralow interfacial tension, wetting reversal, reduced retardation force, and emulsification.

show abstract

Section: Resultsmentioning

confidence: 99%

Microscopic Remaining Oil Distribution Regularity and Enhanced Oil Recovery Methods after Polymer Flooding

Chen,

Cao,

Jiang

et al. 2024

Energy Fuels

View full text Add to dashboard Cite

show abstract

“…In the domain of petroleum engineering, hydraulic fracturing and acidizing techniques are used to enhance reservoir permeability [3]; chemical flooding and gas flooding can change fluid properties, thereby increasing the recovery efficiency of crude oil [4,5], and water injection operations help to maintain and increase reservoir pressure [6]. Due to their characteristics, they have become important methods of increasing production and research topics in the field of petroleum engineering.…”

Section: Introductionmentioning

confidence: 99%

Machine Learning in Reservoir Engineering: A Review

Zhou,

Liu,

Liu

et al. 2024

Processes

View full text Add to dashboard Cite

With the rapid progress of big data and artificial intelligence, machine learning technologies such as learning and adaptive control have emerged as a research focus in petroleum engineering. They have various applications in oilfield development, such as parameter prediction, optimization scheme deployment, and performance evaluation. This paper provides a comprehensive review of these applications in three key scenarios of petroleum engineering, namely hydraulic fracturing and acidizing, chemical flooding and gas flooding, and water injection. This article first introduces the steps and methods of machine learning processing in these scenarios, then discusses the advantages, disadvantages, existing challenges, and future prospects of these machine learning methods. Furthermore, this article compares and contrasts the strengths and weaknesses of these machine learning methods, aiming to help researchers select and improve their methods. Finally, this paper identifies some potential development trends and research directions of machine learning in petroleum engineering based on the current issues.

show abstract

“…The development of conventional reservoirs cannot meet the current growing oil demand. Unconventional oil resources with high temperature, high salt, low permeability, and heterogeneity have been taken as the focus of development. − Due to the complex reservoir conditions, a variety of effective oil recovery methods have been developed for enhanced oil recovery (EOR). − Among them, chemical flooding has received significant attention in tertiary oil recovery. − At present, various types of surfactants are widely used in oil fields, including anionic surfactants, cationic surfactants, nonionic surfactants, and zwitterionic surfactants. − However, each surfactant has its limitations in application. Therefore, the development of surfactants with high surface activity and good environmental tolerance will be an important research direction. − …”

Section: Introductionmentioning

confidence: 99%

Properties and Aggregation Behavior of Gemini Surfactants for Heavy Oil Recovery in High Temperature and Salinity Conditions

Wang,

Zheng,

Shi

et al. 2023

Energy Fuels

View full text Add to dashboard Cite

In this paper, the thermal stability of the surfactant CEA-n molecules with different structures was determined by thermal gravimetric analysis. The aggregation behavior in aqueous solution was studied by dynamic light scattering and transmission electron microscopy (TEM). The interfacial behavior, emulsification performance, and heavy oil universality of the surfactants under high temperature and high salinity conditions were evaluated by interfacial tension (IFT), viscosity reduction rate (VRR), and multiple light scattering. Also, microscopic oil displacement experiments were performed to investigate the oil displacement mechanism of the surfactant. Results indicated that the surfactant molecules had good thermal stability. The initial decomposition temperature (T i ) of surfactants CEA-n was greater than 280 °C. The average hydrodynamic radius (R h ) of the surfactant CEA-2 system after aging was larger than that of the unaged system, and the aggregation of CEA-2 molecules was promoted by the addition of NaCl. Moreover, the IFT of surfactant CEA-2 had a small change with the increase of aging temperature (100−300 °C), which could be maintained on the order of 10 −1 mN/m. And the VRR of the surfactants was higher than 95.0%, showing good emulsifying and viscosity reduction effects. Although the turbiscan stability index (TSI) value of the oil LD2-1 emulsion system was the lowest and had the best emulsion stability, the VRR between the surfactant and oil NB35-2 could reach more than 99.0%, indicating that CEA-2 had good heavy oil universality. Furthermore, the sand-pack flooding experiments were also carried out to confirm the great potential of the Gemini surfactant systems for heavy oil recovery.

show abstract

A review of crude oil emulsification and multiphase flows in chemical flooding

Cited by 6 publications

References 136 publications

Microscopic Remaining Oil Distribution Regularity and Enhanced Oil Recovery Methods after Polymer Flooding

Microscopic Remaining Oil Distribution Regularity and Enhanced Oil Recovery Methods after Polymer Flooding

Machine Learning in Reservoir Engineering: A Review

Properties and Aggregation Behavior of Gemini Surfactants for Heavy Oil Recovery in High Temperature and Salinity Conditions

Contact Info

Product

Resources

About