scholarly journals Simultaneous injection of chemical agents and carbon dioxide to enhance the sweep efficiency from fractured tight core samples

2021 ◽  
Vol 7 ◽  
pp. 5639-5646
Author(s):  
Rahmad Syah ◽  
S.M. Alizadeh ◽  
Leila Darvishzadeh ◽  
Marischa Elveny ◽  
Maryam Abedi ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Sweep Efficiency ◽  
Simultaneous Injection ◽  
Core Samples ◽  
Chemical Agents

scholarly journals Surfactant-Polymer Interactions in a Combined Enhanced Oil Recovery Flooding

Energies ◽  
2020 ◽  
Vol 13 (24) ◽  
pp. 6520
Author(s):  
Pablo Druetta ◽  
Francesco Picchioni
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Combined Processes ◽  
Sweep Efficiency ◽  
Two Phase ◽  
Chemical Agents ◽  
Chemical Eor ◽  
Eor Processes ◽  
Adsorption Rates ◽  
Polymer Interaction

The traditional Enhanced Oil Recovery (EOR) processes allow improving the performance of mature oilfields after waterflooding projects. Chemical EOR processes modify different physical properties of the fluids and/or the rock in order to mobilize the oil that remains trapped. Furthermore, combined processes have been proposed to improve the performance, using the properties and synergy of the chemical agents. This paper presents a novel simulator developed for a combined surfactant/polymer flooding in EOR processes. It studies the flow of a two-phase, five-component system (aqueous and organic phases with water, petroleum, surfactant, polymer and salt) in porous media. Polymer and surfactant together affect each other’s interfacial and rheological properties as well as the adsorption rates. This is known in the industry as Surfactant-Polymer Interaction (SPI). The simulations showed that optimum results occur when both chemical agents are injected overlapped, with the polymer in the first place. This procedure decreases the surfactant’s adsorption rates, rendering higher recovery factors. The presence of the salt as fifth component slightly modifies the adsorption rates of both polymer and surfactant, but its influence on the phase behavior allows increasing the surfactant’s sweep efficiency.

Petrophysical Changes of Sandstone Due to Salt Precipitation and Fines Migration During Carbon Dioxide Injection

2020 ◽  
Vol 17 (2) ◽  
pp. 1207-1213 ◽  
Author(s):  
Muhammad Aslam Md Yusof ◽  
Mohamed Zamrud Zainal ◽  
Ahmad Kamal Idris ◽  
Mohamad Arif Ibrahim ◽  
Shahrul Rizzal M. Yusof ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Damage Mechanism ◽  
Salt Precipitation ◽  
Carbon Dioxide Injection ◽  
Fines Migration ◽  
Flow Rates ◽  
The Core ◽  
Core Samples ◽  
Sandstone Rock ◽  
Porosity And Permeability

Sequestration of Carbon Dioxide (CO2) in sandstone formation filled by brine aquifers is widely considered a promising option to reduce the CO2 concentration in the atmosphere. However, the injection of reactive CO2 into sandstone rock creates injectivity problems because of CO2-brine-rock interactions. The injection flow rate and CO2-fluid-rock exposure conditions are important factors that control the intensity of the reactions. The focus of this research was therefore on evaluating the petrophysical modifications in sandstone core samples at distinct flow rates using different CO2 injection schemes. In this research, the porosity and permeability of Berea sandstone samples were measured using PoroPerm equipment. The core samples were initially saturated with dead brine (30 g/l NaCl) followed by injection either by supercritical CO2 (scCO2) only, CO2-saturated brine only and CO2-saturated brine together with scCO2 at different flow rates. During injection, the differential pressure between the core inlet face and outlet face were recorded. Fines from the produced effluent were separated and collected for characterization using Field Emission Scanning Electron Microscope and Energy Dispersive X-ray Spectroscopy (FESEM-EDX). Post-injection porosity and permeability of the core samples were measured and compared with the pre-injection data to monitor changes. All sandstone core specimens showed favorable storage capability features in the form of capillary residual trapping with residual CO2 saturation ranging from 40% to 48%. In addition, all samples experienced important changes in their petrophysical characteristics, which were more pronounced in the event of absolute porosity and permeability, which decreased from 20%–51% to 4%–32%. The suggested harm mechanism is primarily owing to salt precipitation and fines migration. Supported by FESEM images, the proposed damage mechanism is mainly due to salt precipitation and fines migration.

Mobility of Ethomeen C12 and Carbon Dioxide (CO2) Foam at High Temperature/High Salinity and in Carbonate Cores

SPE Journal ◽  
2016 ◽  
Vol 21 (04) ◽  
pp. 1151-1163 ◽  
Author(s):  
Leyu Cui ◽  
Kun Ma ◽  
Maura Puerto ◽  
Ahmed A. Abdala ◽  
Ivan Tanakov ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
High Temperature ◽  
High Salinity ◽  
Local Equilibrium ◽  
Co2 Flooding ◽  
Sweep Efficiency ◽  
Co2 Foam ◽  
Foam Model ◽  
Wide Range ◽  
Carbon Dioxide Co2

Summary The low viscosity and density of carbon dioxide (CO2) usually result in the poor sweep efficiency in CO2-flooding processes, especially in heterogeneous formations. Foam is a promising method to control the mobility and thus reduce the CO2 bypass because of the gravity override and heterogeneity of formations. A switchable surfactant, Ethomeen C12, has been reported as an effective CO2-foaming agent in a sandpack with low adsorption on pure-carbonate minerals. Here, the low mobility of Ethomeen C12/CO2 foam at high temperature (120 °C), high pressure (3,400 psi), and high salinity [22 wt% of total dissolved solids (TDS)] was demonstrated in Silurian dolomite cores and in a wide range of foam qualities. The influence of various parameters, including aqueous solubility, thermal and chemical stability, flow rate, foam quality, salinity, temperature, and minimum-pressure gradient (MPG), on CO2 foam was discussed. A local-equilibrium foam model, the dry-out foam model, was used to fit the experimental data for reservoir simulation.

Simultaneous Injection of Water and Polymer (SIWAP) to Improve Oil Recovery and Sweep Efficiency from Layered Carbonate Reservoirs

2011 ◽  
Author(s):  
Shehadeh K. Masalmeh ◽  
Carl P.A. Blom ◽  
Esther C.M. Vermolen ◽  
Andrey Bychkov ◽  
L. Bart M. Wassing
Keyword(s):  
Oil Recovery ◽  
Carbonate Reservoirs ◽  
Sweep Efficiency ◽  
Simultaneous Injection

Visualizing and Quantifying Generation, Propagation, and Sweep of Nanocellulose-Strengthened Carbon Dioxide Foam in a Complex 2D Heterogeneous Fracture Network Model

SPE Journal ◽  
2021 ◽  
pp. 1-14
Author(s):  
Bing Wei ◽  
Qingtao Tian ◽  
Shengen Chen ◽  
Xingguang Xu ◽  
Dianlin Wang ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Network Model ◽  
Gravitational Effect ◽  
Fracture Network ◽  
Sweep Efficiency ◽  
Co2 Foam ◽  
Reservoir Conditions ◽  
Foam Film ◽  
Carbon Dioxide Co2

Summary There exist two main issues hampering the wide application and development of carbon dioxide (CO2) foam in conformance improvement and CO2 mobility reduction in fractured systems: (1) instability of foam film under reservoir conditions and (2) uncertainties of foam flow in complex fractures. To address these two issues, we previously developed a series of nanocellulose-strengthened CO2 foam (referred to as NCF-st-CO2 foam), while the primary goal of this work is to thoroughly elucidate generation, propagation, and sweep of NCF-st-CO2 foam in a visual 2D heterogeneous fracture network model. NCF-st-CO2 foam outperformed CO2 foam in reducing gas mobility during either coinjection (COI) or surfactant-alternating-gas (SAG) injection, and the threshold foam quality was approximately 0.67. Foam creation was increased with the total superficial velocity for CO2 foam and almost stayed constant for NCF-st-CO2 foam in fractures during COI. For SAG, large surfactant slug could prevent CO2 from early breakthrough and facilitate foaming in situ. The improved sweep efficiency induced by NCF-st-CO2 foam occurred near the producer for both COI and SAG. Film division and behind mainly led to foam generation in the fracture model. Gravity segregation and override was insignificant during COI but became noticeable during SAG, which caused the sweep efficiency decrease by 3 to 9%. Owing to the enhanced film, NCF-st-CO2 foam enabled mitigation of the gravitational effect, especially around the producer.

Nanoparticles Stabilized Carbon Dioxide Foams in Sandstone and Limestone Reservoir

2015 ◽  
Vol 1119 ◽  
pp. 170-174
Author(s):  
Azlinda Azizi ◽  
Hazlina Husin ◽  
Nurul Aimi Ghazali ◽  
Muhammad Kamil Khairudin ◽  
Arina Sauki ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Experimental Study ◽  
Oil Recovery ◽  
Harsh Environment ◽  
Experimental Setup ◽  
Residual Oil ◽  
Flow Rates ◽  
Core Samples ◽  
Porosity Reduction ◽  
Sandstone Rock

The use of nanoparticles with carbon dioxide foams has been proposed for enhanced oil recovery due to their robust chemical stability in harsh environment. The experimental study was performed by using nanoparticles stabilized carbon dioxide foams to study their recovery of residual oil by varying the carbon dioxide flow rates on different core samples such as sandstone and limestone. Experimental setup was divided into two different kinds of experiments which are the injection of carbon dioxide foams and the injection of nanoparticles assisted carbon dioxide foams in both sandstone and limestone core samples. For the CO2 foam injection, it was found that limestone has higher oil recovery than sandstone rock samples with 38.67% recovery and 36.36% recovery for sandstone. With the nanoparticles assisted injection, the crude oil recovery increased to 41.82% and 45.33% for sandstone and limestone respectively. Limestone showed the higher porosity reduction at the end of experiment compared to sandstone with the porosity of 7.56% on limestone and 12.49% on sandstone respectively. This is due to the nanoparticles strongly absorbed at the limestone surfaces containing calcite component.

A New Hydrocarbon Elastomer. II. Properties of an Ethylene-Propylene-Nonconjugated Diene Terpolymer

1962 ◽  
Vol 35 (4) ◽  
pp. 1126-1141 ◽  
Author(s):  
J. J. Verbanc ◽  
M. S. Fawcett ◽  
E. J. Goldberg
Keyword(s):  
Carbon Dioxide ◽  
Thermal Conductivity ◽  
Thermal Diffusivity ◽  
Amorphous Polymer ◽  
Practical Significance ◽  
Prolonged Storage ◽  
Hydrocarbon Solvents ◽  
Chemical Agents ◽  
Thermal Data ◽  
General Appearance

Abstract A new hydrocarbon elastomer has been synthesized from petrochemical intermediates using coordination catalysis. This amorphous polymer resembles commercial diene elastomers in general appearance, is completely soluble in hydrocarbon and chlorinated hydrocarbon solvents, and is stable to prolonged storage. It can be vulcanized effectively by the use of accelerated sulfur systems and reinforced by numerous fillers such as carbon blacks, clays, and certain silicas. Reinforced vulcanizates are strong, resilient, and extremely resistant to oxygen, ozone, heat, light, and many chemical agents. Properly compounded vulcanizates exhibit excellent electrical and low temperature properties. Permeability to gases, specifically nitrogen, oxygen, and carbon dioxide, parallels natural rubber. Thermal diffusivity and thermal conductivity are ∼15% greater than polyisoprene. The practical significance of the thermal data remains to be determined.

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