Linear rheology of nanoparticle-enhanced viscoelastic surfactants

2020 ◽  
Vol 300 ◽  
pp. 112215 ◽  
Author(s):  
Brayan F. García ◽  
Soheil Saraji
Keyword(s):  
Viscoelastic Surfactants

scholarly journals Research progress of viscoelastic surfactants for enhanced oil recovery

2021 ◽  
pp. 014459872098020
Author(s):  
Ruizhi Hu ◽  
Shanfa Tang ◽  
Musa Mpelwa ◽  
Zhaowen Jiang ◽  
Shuyun Feng
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
High Efficiency ◽  
Research Progress ◽  
Surfactant Flooding ◽  
Sweep Efficiency ◽  
The World ◽  
Washing Efficiency ◽  
Viscoelastic Surfactants ◽  
Viscoelastic Surfactant

Although new energy has been widely used in our lives, oil is still one of the main energy sources in the world. After the application of traditional oil recovery methods, there are still a large number of oil layers that have not been exploited, and there is still a need to further increase oil recovery to meet the urgent need for oil in the world economic development. Chemically enhanced oil recovery (CEOR) is considered to be a kind of effective enhanced oil recovery technology, which has achieved good results in the field, but these technologies cannot simultaneously effectively improve oil sweep efficiency, oil washing efficiency, good injectability, and reservoir environment adaptability. Viscoelastic surfactants (VES) have unique micelle structure and aggregation behavior, high efficiency in reducing the interfacial tension of oil and water, and the most important and unique viscoelasticity, etc., which has attracted the attention of academics and field experts and introduced into the technical research of enhanced oil recovery. In this paper, the mechanism and research status of viscoelastic surfactant flooding are discussed in detail and focused, and the results of viscoelastic surfactant flooding experiments under different conditions are summarized. Finally, the problems to be solved by viscoelastic surfactant flooding are introduced, and the countermeasures to solve the problems are put forward. This overview presents extensive information about viscoelastic surfactant flooding used for EOR, and is intended to help researchers and professionals in this field understand the current situation.

Several Decades of Fluid Diversion Evolution, Is There a Good Solution?

2021 ◽  
Author(s):  
Alberto Casero ◽  
Ahmed M. Gomaa
Keyword(s):  
Treatment Success ◽  
Optimal Solution ◽  
Injection Rate ◽  
Testing Procedures ◽  
Well Completion ◽  
Scale Inhibition ◽  
Viscoelastic Surfactants ◽  
Sandstone Formation ◽  
Operational Constraints ◽  
Selection Of

Abstract The success of any matrix treatment depends upon the complete coverage of all zones. Consequently, the selection of the diversion technology is critical for treatment success. While various types of diverting agents are commercially available, the proper selection of optimal diverter depends on many factors, including well completion and history, compatibility with reservoir and treatment fluids, treatment objectives, operational constraints, and safety and environment considerations. The study will cover five major types of non-mechanical diversion technologies considered as potential solutions for offshore deepwater oil reservoirs: dynamic diversion, relative permeability modifiers (RPM), viscoelastic surfactants (VES), particulate diversion, and perforation diversion. All of them, but a dynamic diversion, are based on different chemicals or products to be added to the injected treatment fluid, and occasionally some can be complementary to each other. Given the offshore and deepwater settings, mechanical diversion techniques were not covered in the study, aiming to find a solution that would achieve acceptable diversion while minimizing operational effort, which would enable riser-less intervention and the use of light intervention techniques. This study was driven by the need to effectively stimulate a 500ft of a cased and perforated interval with a permeability of 500 md, and injection rate limited to 16 bpm due to completion limitations. The sandstone formation, with static in situ temperature of 270F, was far beyond the applicability of dynamic diversion and, to achieve the desired full coverage for the planned scale inhibition treatment required and combination with another diverter system was needed. The process applied included compatibility tests, regained permeability tests, and test well trials. Depending on the specific diversion product analyzed the testing procedures were adapted to obtain the information to properly guide to the optimal solution.

Development of smart viscoelastic surfactants and its applications in fracturing fluid: A review

2020 ◽  
Vol 190 ◽  
pp. 107107 ◽  
Author(s):  
Wanli Kang ◽  
Silvia John Mushi ◽  
Hongbin Yang ◽  
Pengxiang Wang ◽  
Xiaoyu Hou
Keyword(s):  
Fracturing Fluid ◽  
Viscoelastic Surfactants

A New Class of Viscoelastic Surfactants for Enhanced Oil Recovery

2012 ◽  
Author(s):  
Lorenz Siggel ◽  
Monika Santa ◽  
Markus Hansch ◽  
Maik Nowak ◽  
Meik Ranft ◽  
...  
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
New Class ◽  
Viscoelastic Surfactants

Propagation and Retention of Viscoelastic Surfactants Following Matrix-Acidizing Treatments in Carbonate Cores

SPE Journal ◽  
2011 ◽  
Vol 16 (04) ◽  
pp. 993-1001 ◽  
Author(s):  
M.. Yu ◽  
M.A.. A. Mahmoud ◽  
H.A.. A. Nasr-El-Din
Keyword(s):  
Flow Rate ◽  
Injection Rate ◽  
Low Flow ◽  
Gas Wells ◽  
The Core ◽  
Injection Flow ◽  
Carbonate Cores ◽  
Glycol Monobutyl Ether ◽  
Viscoelastic Surfactants ◽  
Viscoelastic Surfactant

Summary Viscoelastic surfactants have been used extensively in the field. They have the ability to form long rod-like micelles with an increase in pH and calcium concentration, which results in increasing the viscosity and elasticity of partially spent acids. There is ongoing debate in the industry about whether the gel generated by these surfactants causes formation damage, especially in dry-gas wells. The objectives of the present study are to quantitatively determine surfactant retention in calcite cores and assess the benefits of using mutual solvents to break the surfactant gel formed inside the cores. Coreflood tests were performed using Pink Desert limestone cores (1.5 in. in diameter and 20 in. in length). The cores were injected with a surfactant-based acid that contained 15 wt% HCl, 7 vol% viscoelastic surfactant, and 0.3 vol% corrosion inhibitor. Coreflood tests were conducted at a constant injection flow rate ranging from 1.5 to 40 cm3/min. Surfactant and calcium concentrations were measured in the injected acid and core effluent. Mutual solvent (ethylene glycol monobutyl ether) was used in several tests to break surfactant gel. Propagation of viscoelastic surfactants in linear calcite cores was found to be a function of flow rate. Surfactant lagged calcium in the core effluent samples, especially at low flow rates. The volume of acid needed to break through the core and the amount of surfactant retained varied with acid injection rate, and exhibited a minimum at 10 cm3/min. A significant amount of surfactant was retained in the cores. Injection of 2 pore volumes (PV) of 10 vol% mutual solvent removed only 20% of the surfactant injected. Based on these results, there is a need to use internal breakers when surfactant-based acids are used in dry-gas wells or water injectors.

Sign in / Sign up

Export Citation Format

Share Document